• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
  • 引用文献
  • 法律状态
  • 优先权
    • 专利摘要:
    The invention relates to power engineering and makes it possible to increase the maneuverability of a power plant. The power plant contains a gasification unit (U) 1 for coal, heat exchange Y 2. A non-purified gas containing heat; exchangers (then) 18 and 19 with gas-gas service THAT 20 and cooler placed between them. U 3 gas purification, gas turbine and steam turbine units 4 and 5. U 6 methanol synthesis, performed
    公开号:SU1452490A3
    申请号:SU843737249
    申请日:1984-05-14
    公开日:1989-01-15
    发明作者:Гебель Конрад；Мюллер Райнер；Шифферс Ульрих
    申请人:Крафтверк Унион Аг (Фирма)；
    IPC主号:
    专利说明:

    . one
    The invention relates to the energy sector, in particular to maneuverable power plants with coal gasification and methanol production.
    The drawing shows the scheme of the proposed semi-peak power plant.
    The semi-peak power plant contains a coal gasification unit 1, a crude gas exchange unit 2, a gas purification unit 3, a gas turbine unit 4 and a steam turbine unit 5, a methanol synthesis unit 6, a central distribution system 7 of purified gas with a flow-through unit 8 for intermediate storage of the purified gas, connected in parallel to the pipeline 9 purified gas. Installation 1 coal gasification
    1 / Lt Lt /
    CUCt v-. -
    Includes 10 coal gas generator, air decomposition unit P, oxygen receiver 12 and nitrogen receiver 13, included respectively in the pipeline
    14 oxygen and pipe
    15 nitrogen, air compressors 16 connected to the air decomposition unit P, and gas compressor 17 installed on the pipe
    wire 14 of the oxygen outlet connected to the gas generator 10 coal. The heat exchange unit 2 of the crude gas consists of / on: x 10 coal of two heat exchangers 18 and 19 used to produce steam, a gas-gas heat exchanger 20 for heating the purified gas and an adjustment cooler 21 in the gas extraction pipeline from the gas generator. The gas purification installation 3 included in the gas exhaust pipeline from the gas generator 10 after the installation of the crude gas 2 comprises a washer 22, a hydrogen sulfide absorption unit 23, and a sulfur production unit 24. The gas turbine unit 4 is connected to the clean gas pipeline 9 after the gas-gas heat exchanger 20, including the combustion chamber 25, the gas turbine 26 with a generator, and an air compressor 27 connected to the combustion chamber and the air decomposition unit 11 parallel to the compressors 16. Exhaust pipelines gas of the gas turbine 26 included a waste heat boiler 28, to the steam pipe of which steam is connected
    turbine 2U steam turbine, innoch-block 5 with high and low dan cylinders and a generator. The steam turbine unit 5 also contains a condenser, a condensate pump, a feed water tank and feed water pumps 30. The central distribution system 7 contains a purified gas pipeline, in parallel with which a flow-through installation 8 of intermediary storage of purified gas is connected, as well as compressors 31 connected to methanol synthesis unit 6, a mixer 32 on the pipeline 9 of purified gas in front of a gas-gas heat exchanger 20 for mixing the exhaust gases synthesis from the methanol synthesis unit 6 and the mixer 3 on the purified gas pipeline in front of the combustion chamber 25, connected to the nitrogen removal pipeline 15 from the air decomposition unit 11. The flow-through installation 8 of the intermediate storage of purified gas contains a low pressure receiver 34, a high pressure receiver 35 and an pressure boost compressor 36 connected between them, while the receivers 34 and 35 are connected through valves 37 and 38 to the purified gas pipeline 9. Valves 37 and 38 are controlled by a pressure transducer (not shown). If the pressure in line 9 drops below a previously adjusted value, valve 38 opens, and if it rises above the previously set value, valve 37 opens. Methanol synthesis unit 6 consists of three modules 39, 40 and 41 connected in parallel with synthesis reactors 42, separator 43 of methanol, pipelines 44 of regeneration and the circulation compressors 45 installed on them and hydrogen-enrichment stages 46, as well as with pipelines 47 and 48 of synthesis synthesis gases. At the same time, module 39 of the methanol synthesis unit is connected by pipeline 47 to pipelines 44. Recirculation of modules 40 and 41. Modules 39, 40 and 4 are connected by reactors 42 to the pipeline 9 of purified gas through compressors 31. The installation works as follows.
    At nominal mode, block 11
    air decomposition is supplied with compressed air from a compressor 27 driven by a gas turbine

    90
    26 and from at least one air compressor 16 of the air decomposition unit. The oxygen of the air decomposition unit 11 through the oxygen receiver 12 and the compressor 17 is injected into a 10 coal gas generator. In the latter, with the help of oxygen and the injected process steam, COAL, gasification, is fed into the crude gas. Crude gas having a temperature of 800-1600 ° C transfers heat in the heat exchanger 18 of the heat exchange unit 2 of the crude gas, which produces high-pressure steam to feed the high-pressure steam turbine cylinder 29. In the gas-gas heat exchanger 20, the purified gas is heated by the heat of the crude gas sent to the combustion chamber 25 of the gas turbine unit 4. Next, heat is removed from the raw gas in the heat exchanger 19, in which low pressure steam is produced. During nominal operation, this steam is partially supplied to the low pressure cylinder of the steam turbine 29 and is partially used as process steam in a 10 coal gas generator. In the control cooler 21, the raw gas is cooled to a predetermined temperature.
    In the gas cleaning unit .3, the crude gas is cleaned primarily from the washer 22 from dust particles and in the subsequent hydrogen sulfide absorption unit 23 from hydrogen sulfide. The off-gas of the absorption unit 23 containing hydrogen sulphide is converted to sulfur in the sulfur-producing unit 24. The purified gas leaving the gas purification installation 3 is supplied via line 9 to the flow-through installation 8 for the intermediate storage of the purified gas and to other gas consumers. With compressors 31, the purified gas is compressed to the pressure of synthesis and fed to synthesis synthesis reactors 42 of installation 6 of methanol synthesis. In the nominal mode, it is preferable to operate only one module 39 of the methanol synthesis unit, which operates in a continuous synthetic mode. The synthesis gas leaving the synthesis reactor is released from the methanol separator 43 of methanol. The waste gas of synthesis from the methanol separator has a high heat removal capacity compared with the heat removal capacity of the purified gas. Departure
    This synthesis gas can be introduced through ames 32 to the purified gas pipeline 9 and burned in the combustion chamber 25 of the gas turbine unit, thereby replacing part of the purified gas.
    Both other modules 40 and 41, equipped with recirculation pipes 44, are put into operation when there is an excess of purified gas as a result of, for example, a reduction in the power of the gas turbine unit 4 and a decrease in the flow of purified gas into the combustion chamber 25. In modules 40 and 41, the waste synthesis gas through recycle pipelines 44 and hydrogenation enrichment stages 46 is discharged to synthesis reactor 42. In the hydrogenation enrichment stages, a stoichiometric ratio of H and CO equal to two is again achieved due to the addition of hydrogen gas, hydrogenation dressing stations can be included in the pipeline, purified gas in front of synthesis reactors instead of recirculation pipelines. Due to the recycling of flue gases from the synthesis, carbon monoxide is almost completely reacted. In order to preserve a constant amount of inert gases in the gas to be recirculated, small amounts of synthesis synthesis waste gas are diverted to an additionally installed autonomous steam generator (not shown). Alternatively, the waste gas may be partially combusted in the combustion chamber of an additionally installed gas turbine unit (not shown), which may generate electricity to cover the own demand of a semi-peak power plant.
    The gas turbine 26 of the gas turbine unit 4 drives an electric generator and an air compressor 27, which supplies compressed air to the combustion chamber 25 and to the air decomposition unit 11. Since the capacity of the air compressor 27 corresponds to the air flow required for the combustion chamber 25 at full load of the gas turbine unit, to cover the total oxygen demand of the coal gasification unit 1 at full load of the gas turbine unit and during operation of the methanol synthesis unit 39 in operation
    0
    20
    thirty
    25
    This should include at least one air compressor 16. Air compressors 16 supply air to the air decomposition unit 11 even when the gas turbine unit is completely stopped,
    Dp reduce the formation of NOj groups. when burning purified gas to it, 33 nitrogen from the air decomposition unit 11 is mixed through the mixer 33. Due to this, the flame temperature in the combustion chamber 25 is reduced and the formation of the NOy group is reduced. 15 The admixed amounts of nitrogen correspond to the receiving capacity of the gas turbine 26 in this operating mode. Excessive, kevoslemyaemy gas turbine, nitrogen can accumulate in the receiver 13 of nitrogen. If less gas is supplied to the gas turbine with a reduced load, then there may be a lot more nitrogen in certain limits. The hot flue gases from gas turbine 26 are directed to waste heat boiler 28, in which their heat is used to produce steam. The steam and steam from the heat exchange unit 2 of the crude gas produced in the waste-heat boiler is supplied to the steam turbine 29. After the steam turbine, the steam is condensed in a condenser and the condensate is pumped into the feed water tank, from where feedwater pumps 30 feed into the heat recovery boiler 28 and heat exchangers 18
    and 19,
    When the power of the gas turbine unit 4 decreases, the remaining constant amount of gas from the coal gasification unit 1 is countered by the reduced gas flow rate into the combustion chamber 25. This leads to a higher pressure in the pipeline 9 of the purified gas above the previously set pressure and to the operation of the valve 37 of the flow-through installation 8 of the intermediate storage of the purified gas. Through the valve 37, the low pressure receiver 34 is filled first, and then through the pressure compressor 36, the high pressure receiver 35 is also filled. At the same time, the productivity of operating module 39 of methanol synthesis unit 6 is improved. If this is not enough to achieve an equilibrium between the gas outlet and the gas withdrawal, then modules 40 and 41 are put into operation.
    35
    40
    50
    55
    7
    synthesis gas from unit 39 through pipeline 48, hydrogenation stage 46 and compressor 45 is supplied to synthesis reactor 42 of one of the operating modules. When this happens, synthesis reactor waste is heated by synthesis gas in addition to heating through heat exchangers attached to individual modules (not shown). Thanks to this additional heating, modules 40 and 41 can be put into operation as quickly as possible, so that the equilibrium between the production and extraction of gas from the installation 10 coal gasification
    With the gas turbine unit 4 completely disconnected, all the blocks of the methanol synthesis unit 6 are included in the work, which completely accept the purified gas coming from the coal gasification unit 1. This, depending on the power of the methanol synthesis unit 6, may be the amount of gas that leaves the coal gasification unit 1 under normal or somewhat reduced load. When the gas turbine unit 4 is turned off, the air decomposition unit 11 can be supplied with compressed air through air compressors 16. The drive energy for air compressors 16, as well as compressors 17, 31 and 45 is provided by the operation of a steam turbine that receives steam from heat exchangers 18 and 19 of the crude exchange unit 2. gas. With the gas turbine unit 4 completely shut off, all the synthesis synthesis gas from the module 39 of the methanol synthesis unit is fed to the recirculation pipelines 44 of the modules 40 and 41 ..
    If the gas turbine unit 4 is put into operation again, the increased consumption of gas confronts the unchanged yield of purified gas. This leads to a decrease in pressure in the pipeline 9 of the purified gas below a predetermined pressure. This opens the valve 38 flow installation 8 intermediate storage of purified gas. The purified gas now flows from the high-pressure receiver 35 to the pipeline 9 until a predetermined pressure is reached. At the same time, an equilibrium between the output of the purified gas and the need for it is achieved due to the disconnection of individual modules 40 and 41
    15
    Q
    524908
    Installation 6 methanol synthesis. When the gas turbine unit 4 is put into operation, compressed air from the air compressor 27 of the gas turbine 26, which, while the gas turbine does not operate at full load, is not fully utilized in the combustion chamber 25, is again available. Excess air can be supplied to the air decomposition unit 11 so that the performance of the air compressors can be reduced. At the same time, due to the operation of the gas-gas heat exchanger 20, the steam output from the heat exchanger is reduced, but steam is produced in the waste-heat boiler 28, and the steam output increases, as well as
    20 steam turbine power generation. The pressure in the coal gasification unit 1 corresponds to the pressure required for the operation of the combustion chamber 25. This pressure is significantly lower than the pressure required for the operation of methanol synthesis reactors 42, therefore, compressors 31 are required for connection to pipeline 9. Compressors can be used
    30 31 less power, but in this case the installation is provided -. turbine expander in the pipeline 9 purified gas in front of the chamber 25 of combustion. In this turbine expander, some of the energy that is consumed by the compressors connected in front of the gas generator is regenerated.
    The present invention allows to increase the maneuverability of a semi-peak power plant by accumulating gas during a period of reducing the load of the gas turbine unit in a flow-through installation for intermediate storage of purified gas, as well as disconnecting part of the methanol synthesis unit modules and using gas from the storage unit and activating methanol synthesis unit gas turbine unit loads; using the raw gas heat in heat exchangers to produce steam with the gas-gas heat exchanger off; recirculation of methanol synthesis exhaust gases through a hydrogenation unit to the synthesis reactor; mixing the flue gases of synthesis through a mixer to the purified gas supplied to the combustion chamber of the gas G of the urbine unit in
    35
    40
    45
    50
    55
    a period of increasing its load; utilization of waste gases of methanol synthesis in additional autonomous steam turbine and gas turbine units; using a chiller to control the temperature of the purified gas; supplying compressed air to the coal gasification unit both with the compressor of the gas turbine unit and with the compressors of the decomposed gas unit; also by accumulating oxygen and nitrogen from the air decomposition unit in the receivers and using it in various operating modes (Equipment of the power station.
    I
    权利要求:
    Claims (1)
    [1]
    Invention Formula
    I 1. Semi-electric power plant containing gas turbine and steam turbine units, the first of which is equipped with a combustion chamber and an air compressor, and the second with a steam generator connected to the gas outlet of the gas turbine unit, an integrated coal gasification unit with a gas generator and a decomposition unit. | spirit, equipped with at least one air compressor and pipe | Wires oxygen removal in the gas: the reactor and nitrogen, heat exchange installation of crude gas with a steam generation unit and gas-gas heat exchange - Unik m, connected to the combustion chamber of the gas turbine unit via a purified gas, a gas treatment unit, to the outlet of which a gas-gas heat exchanger and a methanol synthesis plant are connected in parallel with pipelines of the cleaned gas; , communicated by outlet pipelines with consumers of methanol, characterized in that, in order to increase maneuverability, the power plant is equipped with a light-weight installation of intermediate storage of purified gas connected in parallel boprovodu discharging the purified gas to the gas-gas heat exchanger, and the methanol synthesis plant is formed as a parallel-connected modules.
    to
    452490)
    pups between each other through the pressurized compressor.
    3. Power plants on p, 1, about t l and
    This is due to the fact that the steam generation unit of the crude gas heat exchange unit has two heat exchangers, between which a gas-gas heat exchanger is located.
    4. The power plant according to claim 1, wherein the at least one of the modules of the methanol synthesis plant comprises a recirculation pipeline with a circulation compressor and hydrogen-enrichment stage placed on it, connected to the synthesis reactor and pipeline flue gases synthesis.
    5. The power plant according to claim 2, characterized in that at least one module of the methanol synthesis unit is connected via an additionally installed mixer to the clean gas pipeline in front of the gas-gas heat exchanger.
    6. The power plant of claim 5, wherein the waste gas pipeline for the synthesis of at least one module of the methanol synthesis plant is connected to the recirculation pipeline for at least one of the Ostadihs modules.
    7. A power plant according to claim 1 or 4, characterized in that piping of waste gases for synthesis of methanol synthesis plant modules are connected to an additionally installed autonomous steam generator and / or steam generator of an additionally installed autonomous steam turbine unit.
    8. A power plant according to claim 1 or 4, characterized in that the flue gas pipelines of the synthesis of the methanol synthesis plant modules are connected to the combustion chamber of an additionally installed autonomous g-g turbine unit.
    9. Power plant pop. 3, characterized in that the heat exchanger, the installation of the crude gas further comprises a gas cooler placed behind the last heat exchanger of the generation unit
    according to claim 1, about t l and - gg pair,
    10 tea as the spread
    The fact that the flow installation for the intermediate storage of purified gas contains low and high pressure receivers,
    10. The power plant according to claim 1, about tl and - so that at least one air compressor of the air decomposition unit is connected II. 145249012
    for a gas compressor-12 air compressor. The power plant of clause I, about the liter of the turbine unit, is that it supplies
    on a nitrogen receiver mounted
    11. The power plant according to claim 1, 1, about tl and-on the nitrogen exhaust pipe of the unit, so that it is equipped with air decomposition and connected to the wife by an oxygen receiver, installed the purified gas pipeline in front of the oxygen exhaust pipe of the gas turbine air decomposition unit, ka.
    类似技术:
    公开号 | 公开日 | 专利标题
    SU1452490A3|1989-01-15|Half-peak-load power station
    US4676063A|1987-06-30|Medium-load power generating station with an integrated coal gasification plant
    FI76626B|1988-07-29|KOMBINERAD GASTURBIN- AONGTURBINANLAEGGNING MED FOERKOPPLAD KOLFOERGASNINGSANLAEGGNING.
    US5265410A|1993-11-30|Power generation system
    EP1982053B1|2014-01-15|Method for increasing the efficiency of an integrated gasification combined cycle
    US4756722A|1988-07-12|Device for gasifying coal
    CA1233324A|1988-03-01|Power generating station with an integrated coalgasification plant
    JP3107533B2|2000-11-13|Apparatus and method for producing electricity and by-producing hydrogen
    FI78163B|1989-02-28|KRAFTVERK MED EN INTEGRERAD KOLFOERGASNINGSANLAEGGNING.
    CN101899329B|2014-07-16|Systems and methods for treating a stream comprising an undesirable emission gas
    JP5193160B2|2013-05-08|Gasification power generation system with carbon dioxide separation and recovery device
    HU213648B|1997-09-29|Partial oxidation process with production of power
    CN103524299B|2017-08-25|A kind of synthesizing methanol and synthesizing methane cogeneration facility
    EP0686231A1|1995-12-13|New power process
    CN101892081A|2010-11-24|Process for chemical poly-generation of coal-based energy
    EP1102926B1|2007-04-25|Fuel gas turbo-expander for oxygen blown gasifiers and related method
    CN102186956B|2015-02-04|Methods and systems for integrated boiler feed water heating
    RU2105040C1|1998-02-20|Combined steam-gas plant with coal plasmathermal gasification
    CN110921615A|2020-03-27|Method for preparing ammonia product by combining high-pressure coal water slurry radiation waste boiler type gasification with low-pressure ammonia synthesis
    CA1241545A|1988-09-06|Medium-load power generating station with anintegrated coal gasification plant
    CN209759340U|2019-12-10|Tail gas recovery system for methanol synthesis process
    RU2713936C1|2020-02-11|Power supply unit with complex recycling of oil and gas industry wastes
    JP2020196663A|2020-12-10|System and method for producing hydrogen by coke in thermal power plant
    CN112239682A|2021-01-19|Gasification device slag water flash evaporation gas comprehensive utilization system and method
    CA1258773A|1989-08-29|Medium-load power generating station with anintegrated coal gasification plant
    同族专利:
    公开号 | 公开日
    IN161813B|1988-02-06|
    AU2884084A|1984-12-06|
    ZA844111B|1984-12-24|
    FI841838A|1984-12-01|
    IE55179B1|1990-06-20|
    DE3464148D1|1987-07-16|
    DK159510C|1991-03-25|
    ES532944A0|1985-03-01|
    FI76625B|1988-07-29|
    EP0127093B1|1987-06-10|
    IE841351L|1984-11-30|
    NO842059L|1984-12-03|
    DK265784A|1984-12-01|
    AU553937B2|1986-07-31|
    DK265784D0|1984-05-30|
    US4608818A|1986-09-02|
    DE3319732A1|1984-12-06|
    GR82052B|1984-12-13|
    FI76625C|1988-11-10|
    ES8503783A1|1985-03-01|
    JPS59231140A|1984-12-25|
    UA5927A1|1994-12-29|
    NO163202B|1990-01-08|
    NO163202C|1990-04-18|
    BR8402606A|1985-04-30|
    AT27726T|1987-06-15|
    JPH0468446B2|1992-11-02|
    MX158082A|1989-01-05|
    DK159510B|1990-10-22|
    CA1235580A|1988-04-26|
    FI841838A0|1984-05-08|
    EP0127093A1|1984-12-05|
    引用文献:
    公开号 | 申请日 | 公开日 | 申请人 | 专利标题
    RU2477421C1|2011-11-21|2013-03-10|Лариса Яковлевна Силантьева|Power generating system|
    RU2652241C1|2017-07-31|2018-04-25|Федеральное государственное казенное военное образовательное учреждение высшего образования "Военный учебно-научный центр Военно-воздушных сил "Военно-воздушная академия имени профессора Н.Е. Жуковского и Ю.А. Гагарина"Министерства обороны Российской Федерации|Power generating system|US2401845A|1943-05-20|1946-06-11|Hydraulic Control Engineering|Hydraulic accumulator|
    GB933584A|1962-05-02|1963-08-08|Conch Int Methane Ltd|A method of gasifying a liquefied gas while producing mechanical energy|
    US3244106A|1963-09-30|1966-04-05|North American Aviation Inc|High pressure pumping device|
    GB1167493A|1966-01-21|1969-10-15|Ici Ltd|Production of Fuel Gas by Reacting Hydrocarbon with Steam|
    DE2024301C3|1970-05-19|1974-07-04|Metallgesellschaft Ag, 6000 Frankfurt|Process for the production of methanol|
    US3849662A|1973-01-02|1974-11-19|Combustion Eng|Combined steam and gas turbine power plant having gasified coal fuel supply|
    US3904386A|1973-10-26|1975-09-09|Us Interior|Combined shift and methanation reaction process for the gasification of carbonaceous materials|
    US3868817A|1973-12-27|1975-03-04|Texaco Inc|Gas turbine process utilizing purified fuel gas|
    DE2425939C2|1974-05-30|1982-11-18|Metallgesellschaft Ag, 6000 Frankfurt|Process for operating a power plant|
    DE2503193A1|1975-01-27|1976-07-29|Linde Ag|PROCESS FOR PRODUCING A HEATING GAS BY PRESSURE GASIFICATION OF CARBON FUELS|
    US4005996A|1975-09-04|1977-02-01|El Paso Natural Gas Company|Methanation process for the production of an alternate fuel for natural gas|
    US4277416A|1977-02-17|1981-07-07|Aminoil, Usa, Inc.|Process for producing methanol|
    US4158145A|1977-10-20|1979-06-12|The United States Of America As Represented By The United States Department Of Energy|Combined compressed air storage-low BTU coal gasification power plant|
    DE2807326C2|1978-02-21|1982-03-18|Steag Ag, 4300 Essen|Method for operating a gas-steam turbine power plant|
    GB2067668A|1980-01-21|1981-07-30|Gen Electric|Control of NOx emissions in a stationary gas turbine|
    US4341069A|1980-04-02|1982-07-27|Mobil Oil Corporation|Method for generating power upon demand|
    GB2075124A|1980-05-05|1981-11-11|Gen Electric|Integrated gasification-methanol synthesis-combined cycle plant|
    DE3161555D1|1980-09-04|1984-01-05|Ici Plc|Synthesis for producing carbon compounds from a carbon oxide/hydrogen synthesis gas|
    US4404414A|1982-09-28|1983-09-13|Mobil Oil Corporation|Conversion of methanol to gasoline|DE3505157A1|1985-02-15|1986-08-21|Krupp Koppers GmbH, 4300 Essen|METHOD FOR GENERATING ELECTRICAL ENERGY IN A COMBINED GAS AND STEAM TURBINE POWER PLANT WITH UPstream COAL GASIFICATION PLANT|
    AT34201T|1985-08-05|1988-05-15|Siemens Ag|COMBINED GAS AND STEAM TURBINE POWER PLANT.|
    US5063732A|1988-05-26|1991-11-12|Calderon Automation, Inc.|Method for repowering existing electric power plant|
    GB8824364D0|1988-10-18|1988-11-23|Kodak Ltd|Photographic silver halide material|
    US5179129A|1991-03-01|1993-01-12|Air Products And Chemicals, Inc.|Staged liquid phase methanol process|
    GB9111157D0|1991-05-23|1991-07-17|Boc Group Plc|Fluid production method and apparatus|
    FR2690711B1|1992-04-29|1995-08-04|Lair Liquide|METHOD FOR IMPLEMENTING A GAS TURBINE GROUP AND COMBINED ENERGY AND AT LEAST ONE AIR GAS ASSEMBLY.|
    US5392594A|1993-02-01|1995-02-28|Air Products And Chemicals, Inc.|Integrated production of fuel gas and oxygenated organic compounds from synthesis gas|
    US5459994A|1993-05-28|1995-10-24|Praxair Technology, Inc.|Gas turbine-air separation plant combination|
    US5666800A|1994-06-14|1997-09-16|Air Products And Chemicals, Inc.|Gasification combined cycle power generation process with heat-integrated chemical production|
    US6698515B2|2000-04-24|2004-03-02|Shell Oil Company|In situ thermal processing of a coal formation using a relatively slow heating rate|
    US6588504B2|2000-04-24|2003-07-08|Shell Oil Company|In situ thermal processing of a coal formation to produce nitrogen and/or sulfur containing formation fluids|
    US6715546B2|2000-04-24|2004-04-06|Shell Oil Company|In situ production of synthesis gas from a hydrocarbon containing formation through a heat source wellbore|
    US6715548B2|2000-04-24|2004-04-06|Shell Oil Company|In situ thermal processing of a hydrocarbon containing formation to produce nitrogen containing formation fluids|
    US6994161B2|2000-04-24|2006-02-07|Kevin Albert Maher|In situ thermal processing of a coal formation with a selected moisture content|
    CA2445415C|2001-04-24|2011-08-30|Harold J. Vinegar|In situ recovery from a oil shale formation|
    CA2357527C|2001-10-01|2009-12-01|Technology Convergence Inc.|Methanol recycle stream|
    WO2003036039A1|2001-10-24|2003-05-01|Shell Internationale Research Maatschappij B.V.|In situ production of a blending agent from a hydrocarbon containing formation|
    FR2844344B1|2002-09-11|2005-04-08|Air Liquide|PLANT FOR PRODUCTION OF LARGE QUANTITIES OF OXYGEN AND / OR NITROGEN|
    US7121341B2|2002-10-24|2006-10-17|Shell Oil Company|Conductor-in-conduit temperature limited heaters|
    NZ567052A|2003-04-24|2009-11-27|Shell Int Research|Thermal process for subsurface formations|
    JP4098181B2|2003-08-05|2008-06-11|株式会社日立製作所|Heavy oil treatment method and heavy oil treatment system|
    EA010678B1|2004-04-23|2008-10-30|Шелл Интернэшнл Рисерч Маатсхаппий Б.В.|Temperature limited heaters used to heat subsurface formations|
    US20060149423A1|2004-11-10|2006-07-06|Barnicki Scott D|Method for satisfying variable power demand|
    DE102004058759A1|2004-11-30|2006-06-01|Vattenfall Europe Generation Ag & Co. Kg|Method for providing a fuel for the gas turbine of an IGCC power plant|
    DE102004058760B4|2004-11-30|2011-08-18|Vattenfall Europe Generation AG & Co. KG, 03050|Method for operating a gas and steam turbine power plant with integrated coal gasification|
    WO2006080057A1|2005-01-26|2006-08-03|Kawasaki Jukogyo Kabushiki Kaisha|Gas turbine apparatus, apparatus for supplying fuel gas and method for suppressing calorie elevation of fuel gas|
    US7942197B2|2005-04-22|2011-05-17|Shell Oil Company|Methods and systems for producing fluid from an in situ conversion process|
    CA2626965C|2005-10-24|2014-10-14|Shell Internationale Research Maatschappij B.V.|Methods of cracking a crude product to produce additional crude products|
    US20070199300A1|2006-02-21|2007-08-30|Scott Macadam|Hybrid oxy-fuel combustion power process|
    US7665291B2|2006-04-04|2010-02-23|General Electric Company|Method and system for heat recovery from dirty gaseous fuel in gasification power plants|
    EP2010754A4|2006-04-21|2016-02-24|Shell Int Research|Adjusting alloy compositions for selected properties in temperature limited heaters|
    US7841401B2|2006-10-20|2010-11-30|Shell Oil Company|Gas injection to inhibit migration during an in situ heat treatment process|
    US8381815B2|2007-04-20|2013-02-26|Shell Oil Company|Production from multiple zones of a tar sands formation|
    CA2700737A1|2007-10-19|2009-04-23|Shell Internationale Research Maatschappij B.V.|Three-phase heaters with common overburden sections for heating subsurface formations|
    JP5566371B2|2008-04-18|2014-08-06|シエル・インターナシヨネイル・リサーチ・マーチヤツピイ・ベー・ウイ|Use of mines and tunnels to treat subsurface hydrocarbon-bearing formations.|
    US20090301054A1|2008-06-04|2009-12-10|Simpson Stanley F|Turbine system having exhaust gas recirculation and reheat|
    CA2738804A1|2008-10-13|2010-04-22|Shell Internationale Research Maatschappij B.V.|Circulated heated transfer fluid heating of subsurface hydrocarbon formations|
    US20100258291A1|2009-04-10|2010-10-14|Everett De St Remey Edward|Heated liners for treating subsurface hydrocarbon containing formations|
    DE102009049914B4|2009-10-15|2011-12-22|Werner Neumann|Coal-fired power plant combined process with integrated methanol production|
    GB2475889B|2009-12-04|2012-06-20|Rifat Al Chalabi|Gassification system|
    US20110162380A1|2010-01-04|2011-07-07|General Electric Company|Method to increase net plant output of a derated igcc plant|
    US9127523B2|2010-04-09|2015-09-08|Shell Oil Company|Barrier methods for use in subsurface hydrocarbon formations|
    US8631866B2|2010-04-09|2014-01-21|Shell Oil Company|Leak detection in circulated fluid systems for heating subsurface formations|
    US8701769B2|2010-04-09|2014-04-22|Shell Oil Company|Methods for treating hydrocarbon formations based on geology|
    US8820406B2|2010-04-09|2014-09-02|Shell Oil Company|Electrodes for electrical current flow heating of subsurface formations with conductive material in wellbore|
    US9016370B2|2011-04-08|2015-04-28|Shell Oil Company|Partial solution mining of hydrocarbon containing layers prior to in situ heat treatment|
    CA2850741A1|2011-10-07|2013-04-11|Manuel Alberto GONZALEZ|Thermal expansion accommodation for circulated fluid systems used to heat subsurface formations|
    US10047594B2|2012-01-23|2018-08-14|Genie Ip B.V.|Heater pattern for in situ thermal processing of a subsurface hydrocarbon containing formation|
    EP2725207A1|2012-10-29|2014-04-30|Siemens Aktiengesellschaft|Power plant having a steam reformer and gas storage device|
    JP6307238B2|2013-10-02|2018-04-04|三菱日立パワーシステムズ株式会社|CO shift reactor and method of operating the CO shift reactor|
    JP2015151912A|2014-02-13|2015-08-24|三菱日立パワーシステムズ株式会社|Gas supply apparatus, power generation plant, and power generation plant control method|
    DE102016103053B4|2016-02-22|2018-10-31|Deutsches Zentrum für Luft- und Raumfahrt e.V.|Gas delivery device, process for providing synthesis gas and power plant|
    法律状态:
    优先权:
    申请号 | 申请日 | 专利标题
    DE19833319732|DE3319732A1|1983-05-31|1983-05-31|MEDIUM-POWER PLANT WITH INTEGRATED COAL GASIFICATION SYSTEM FOR GENERATING ELECTRICITY AND METHANOL|
    [返回顶部]