EP1172525A1 - Méthode de rénovation de centrales à turbine et chaudière et centrales renovées à turbine et chaudière - Google Patents

Méthode de rénovation de centrales à turbine et chaudière et centrales renovées à turbine et chaudière Download PDF

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Publication number
EP1172525A1
EP1172525A1 EP00610072A EP00610072A EP1172525A1 EP 1172525 A1 EP1172525 A1 EP 1172525A1 EP 00610072 A EP00610072 A EP 00610072A EP 00610072 A EP00610072 A EP 00610072A EP 1172525 A1 EP1172525 A1 EP 1172525A1
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EP
European Patent Office
Prior art keywords
boiler
gas
approximately
flue gas
steam
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Withdrawn
Application number
EP00610072A
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German (de)
English (en)
Inventor
Ole Fanoe
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ADB Power ApS
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ADB Power ApS
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Publication date
Application filed by ADB Power ApS filed Critical ADB Power ApS
Priority to EP00610072A priority Critical patent/EP1172525A1/fr
Publication of EP1172525A1 publication Critical patent/EP1172525A1/fr
Withdrawn legal-status Critical Current

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    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23N—REGULATING OR CONTROLLING COMBUSTION
    • F23N5/00—Systems for controlling combustion
    • F23N5/003—Systems for controlling combustion using detectors sensitive to combustion gas properties
    • F23N5/006—Systems for controlling combustion using detectors sensitive to combustion gas properties the detector being sensitive to oxygen
    • 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
    • F01K23/00—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids
    • F01K23/02—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled
    • F01K23/06—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle
    • F01K23/065—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle the combustion taking place in an internal combustion piston engine, e.g. a diesel engine
    • 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
    • F01K23/00—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids
    • F01K23/02—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled
    • F01K23/06—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle
    • F01K23/10—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle with exhaust fluid of one cycle heating the fluid in another cycle
    • F01K23/103—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle with exhaust fluid of one cycle heating the fluid in another cycle with afterburner in exhaust boiler
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23N—REGULATING OR CONTROLLING COMBUSTION
    • F23N5/00—Systems for controlling combustion
    • F23N5/003—Systems for controlling combustion using detectors sensitive to combustion gas properties

Definitions

  • the present invention relates to a method of repowering existing boiler turbine generator plants and achieving the optimum cost-efficient output as well as such repowered plants per se.
  • the thermal efficiency of a boiler turbine generator plant may be increased by repowering the BTG plant with an internal combustion engine or a gas turbine.
  • Repowering entails that the power output and thermal efficiency of the BTG system are increased by combining the BTG system with a gas turbine or an internal combustion engine using the energy in the exhaust gas of the engine by introducing the exhaust gas into the boiler space as described in U.S. patent No. 4,928,635 and the PCT publication WO 99/23360 disclosing that the thermal efficiency can be further increased by carefully optimising the introduction of the engine exhaust gas into the boiler space.
  • a staged combustion leading to a NO x -reduction as previously disclosed in the Japanese patent JP 64-22328 (89).
  • the background of the latter method is described in greater detail in a paper from Mitsubishi Heavy Industry Vol 26. No. 4 (1989).
  • a repowered boiler turbine generator plant comprising one or more oil-fired or pulverised coal-fired boilers, each boiler generating steam supplied through a steam piping to one or more steam turbines, each of which being connected with a power generator; one or more gas turbines or internal combustion engines, each of which being connected with a generator and each of which supplying the boiler with exhaust gas; a wind-box for the boiler having a burner being supplied with fuel; a superheater and optionally a reheater and a hot economiser upstream of an outlet piping for flue gas from the boiler; a steam piping for passing steam from the boiler through the superheater to the steam turbine(s); optionally a catalyst downstream of the hot economiser for reducing the content of NO x in the flue gas; means for adding ammonia or urea upstream of the catalyst, if present; and optionally a bypass for flue gas from the boiler to the catalyst; which plant further comprises
  • the plant may further comprise a cold economiser downstream of the superheater and the catalyst, if present, for cooling the flue gas to a temperature normally used to prevent sulphuric acid corrosion at the cold end of the economiser and for preheating said boiler feed water.
  • the plant according to the invention may further comprise a heat exchanger using the heat from engine cooling medium, if available, for additional preheating of said boiler feed water.
  • a method of repowering boiler turbine generator plants comprising one or more oil-fired or pulverized coal-fired boilers, each boiler generating steam supplied through a steam piping to one or more steam turbines, each of which being connected with a power generator; one or more gas turbines or internal combustion engines, each of which being connected with a generator and each of which supplying the boiler with exhaust gas; a wind-box for the boiler having a burner being supplied with fuel; the flue gas of said boiler being passed to an outlet piping for flue gas through a superheater and optionally a reheater and a hot economiser for said steam being passed through the steam piping; said flue gas optionally being passed through a catalyst for reducing the content of NO x in the flue gas, in which case ammonia or urea is added upstream of the catalyst; and the temperature at the inlet to the catalyst, if necessary, being maintained at the required level by bypassing the superheater with flue gas
  • the method according to the invention further comprises the step of controlling the amount of fuel to obtain a flue gas having a minimum content of oxygen between approximately 1 % and approximately 4% by volume as a dry gas, or having such a content of oxygen which generates approximately between 100 ppm and approximately 500 ppm by volume as a dry gas of CO, whichever oxygen content is the highest, and more preferably the method according to the invention further comprises the step of controlling the amount of fuel to obtain a flue gas having a content of oxygen of approximately 3 % by volume as a dry gas, or having such a content of oxygen generating approximately at least 100 ppm by volume as a dry gas of CO, whichever oxygen content is the highest.
  • the size of the gas turbine(s) or the internal combustion engine(s) is selected so that the exhaust gas with the optionally added heated air provides said stable combustion in the boiler with the amount of fuel to produce steam in an amount required to generate 95 to 100 % of the output of the power generator in comparison with the use of heated air alone for the combustion at full load.
  • a prior-art boiler turbine generator plant pre-heater of air for the combustion in the boiler is replaced by a cold economiser cooling the flue gas to a temperature normally used to prevent sulphuric acid corrosion at the cold end of the economiser, and the heat from said economiser used to heat boiler feed water.
  • the heat from engine cooling medium if available, is used for additional preheating of said boiler feed water.
  • Fig. 1 shows a schematic diagram of a boiler turbine generator plant being repowered by an embodiment of the method according to the invention.
  • All exhaust gas from the gas turbines or internal combustion engines 5 is supplied to the wind-box 7 of the boiler 1 and the boiler 1 is fired to achieve normal maximum output of the steam turbine generator(s) 2.
  • the exhaust gas from the gas turbine(s) or internal combustion engine(s) 5 is optionally mixed with the preheated air necessary to achieve stable combustion in the boiler.
  • the amount of exhaust gas used corresponds to the minimum requirement for combustion in the boiler 1 and to the maximum requirement for generating a fluegas from the boiler 1 with either an oxygen (O 2 ) content generating in the flue gas a CO content of maximum approximately 100 ppm to approximately 1000 ppm, more preferred approximately 100 to approximately 500 ppm, and especially approximately at least 100 ppm by volume as a dry gas or other maximum values acceptable to the plant owner and authorities, or alternatively approximately 1 % to approximately 6%, more preferred approximately 1 % to approximately 4%, and especially 1 % O 2 by volume as a dry gas, whichever oxygen content is the highest.
  • O 2 oxygen
  • the pre-heater of air for the combustion existing in prior-art plants is replaced by a cold economiser 12 generating heat for heating boiler feed water 11 and any heat from engine cooling is also used for heating boiler feed water.
  • This novel boiler feed water heating replaces otherwise necessary extraction of steam from the steam turbine 2 for feed water preheating and thereby increases the steam turbine output and compensates together with the increased combustion gas temperature and amount for the lower furnace temperature because of the reduced oxygen-content in the boiler combustion gas.
  • the NO x -emission is minimal and may be reduced further by selective catalytic NO x -reduction with the catalyst 13 located between the boiler and the new economiser.
  • the specific CO 2 -emission is minimal at the preferred operational conditions. Surprisingly it has been found that the maximum thermal efficiency is obtained at operational conditions differing from the preferred operational conditions of the method according to the invention.
  • Fig. 1 The repowering process as schematically shown in Fig. 1 comprises the following elements:
  • Fig. 1 shows the basic elements of a boiler turbine generator (BTG) plant repowered by use of the method according to the invention.
  • the principle is described for a system with one boiler 1.
  • the steam produced in the boiler 1 is supplied to a steam turbine 2.
  • Steam is extracted from the turbine 4 for internal use in the boiler plant or for use as process steam outside the boiler plant.
  • the steam turbine 2 is powering a generator 3.
  • the boiler steam turbine cycle may be a simple cycle system or a reheat type cycle.
  • the engine 5 may be formed of one or more gas turbines powered by gas or an internal combustion engine powered by heavy fuel oil or residual oil (i.e. an oil with a viscosity up to 10,000 cSt at 100 C).
  • All of the exhaust gas from the engines is supplied to the wind-box 7 of the boiler 1. If necessary, air 8 is added to the exhaust gas.
  • the air 8 is heated by steam 9.
  • the oxygen content in the gas used for combustion, if necessary with addition of air 8, corresponds to the minimum required amount for securing stable combustion in the boiler 1.
  • Existing burners in the boiler are preferably changed to a type 16 with two gas inlet chambers of which one can be closed with a damper for operation of the boiler on fresh air only.
  • the fuel 17 fed into the boiler 1 might be heavy fuel oil, residual oil or coal.
  • the minimum oxygen content in the combustion gas is in the range of 13.5-13.8 % O 2 by volume on dry basis.
  • the amount of gas used by the combustion for a given amount of fuel 17 fed into the boiler 1 at full load condition for the steam turbine generator is controlled by the oxygen content and the CO-content in the flue gas discharged from the boiler 1 through the piping 18.
  • the amount of gas used by the combustion corresponds to an amount leaving an oxygen content in the flue gas discharged through piping 18, which generate an CO content of maximum approximately 100 ppm by volume on dry basis or other maximum values acceptable to the plant owner and authorities.
  • the oxygen content has to be at least 1 % by volume on dry basis to ensure stable boiler operation.
  • the engines 5 At steam turbine generator full-load conditions the engines 5, in case of gas turbines, operate at 95-100% of full-load conditions at given ambient conditions, whereas, if the engines 5 are internal combustion engines, the engines 5 may operate in the range 85-100 % of full-load conditions.
  • One or more engines 5 may be used for each boiler 1 depending on the amount of exhaust gas at full load for each engine and for required part load operation conditions.
  • the combustion temperature is reduced.
  • the mass flow of gas through the boiler 1 is however increased, whereby the transfer of heat in the boiler part from the superheater 21 to the hot economiser 22 is increased. Further the apparent boiler efficiency is increased, because the higher temperature of the combustion gas compared with air compensates for the reduced combustion temperature.
  • the heat energy from the cold economiser 12 is used for heating of boiler feed water 11. If internal combustion engines are used, the heat energy in the cooling water 10 is also used for heating of the boiler feed water 11 by means of the heat exchanger 20.
  • the heating of the boiler feed water by means of waste heat reduces the amount of extracted steam 4, whereby the steam turbine generator output is increased for same steam supply conditions through steam piping 19. In any case the output from the steam turbine generator 3 after repowering can be kept at full load at 95-100 % of the maximum output when using air for the combustion.
  • the temperature at the inlet to the superheater 21 is also reduced and it should therefore be checked, if the wall temperature comes near the ash sticking temperature. This is even more necessary, if the fuel 17 for the boiler 1 is replaced with residual oil, which with its higher content of vanadium has a reduced ash sticking temperature. If critical, the first superheater should be replaced with another design coping with this problem.
  • a catalyst 13 is placed between the boiler 1 and the cold economiser 12.
  • the catalyst 13 is used for selective catalytic NO x reduction.
  • urea or ammonia 14 is injected upstream the catalyst 13.
  • the temperature of the flue gas at the inlet of the catalyst 13 is kept at the required high level by bypassing 15 flue gas.
  • a filter is installed downstream of the economiser 12 to reduce the particulate content to the required level and a desulphurisation system is installed after the filter.
  • the flue gas after the desulphurisation system is heated by use of a gas/gas heat exchanger using the heat of exhaust gas at the inlet of the desulphurisation system.
  • the method according to the invention is described with reference to a system comprising of a 250 MW reheat type boiler steam turbine generator plant repowered with one to four GTX 100 gas turbines operating on natural gas and the boiler converted into operating on residual oil having a viscosity up to 10,000 cSt at 100°C.
  • the natural gas has a lower heat of combustion of 45,130 kJ/kg and the residual oil a lower heat of combustion of 39,800 kJ/kg.
  • the ambient temperature is 25 °C and 60 % RH at sea level.
  • the gas/power cost level in equal units is 0.266 and the residual oil cost to the power cost level in equal units is similar 0.266.
  • the oxygen content after the boiler generating 100 ppm CO by volume on dry basis is 3%.
  • Case 2.9 the gas turbine size is assumed adjusted geometrically to the preferred operational conditions: Case 1 Case 2 Case 2.9 Case 3 Case 4 Total power/steam turbine power 116 % 132 % 146 % 148 % 164 % Engine Exhaust O 2 % Vol Dry 11.8 11.8 11.8 11.8 11.8 11.8 Engine Exhaust temperature °C 550 550 550 550 550 Economiser Outlet temp.
  • the optimum economy is achieved, where the existing steam turbine after repowering may be operated in the range of 95-100 % of the normal maximum output, when using air by the combustion and gas turbines are operated at full load at given ambient conditions and only either marginal extra air is needed at inlet of the boiler or a marginal higher oxygen content at the outlet boiler compared to the optimum condition.
  • Case 4 and Case 2.9 The main differences between Case 4 and Case 2.9 are that the specific flue gas amount is 22 % higher in Case 4 compared to Case 2.9. The flue gas mass flow itself is 37% higher in Case 4 compared to Case 2.9.
  • the ratio between the specific gas cost and the specific oil cost at equal metric units is assumed to be: 0.6 ⁇ gas cost/oil cost ⁇ 1.17.

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  • Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Engine Equipment That Uses Special Cycles (AREA)
EP00610072A 2000-07-12 2000-07-12 Méthode de rénovation de centrales à turbine et chaudière et centrales renovées à turbine et chaudière Withdrawn EP1172525A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
EP00610072A EP1172525A1 (fr) 2000-07-12 2000-07-12 Méthode de rénovation de centrales à turbine et chaudière et centrales renovées à turbine et chaudière

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Application Number Priority Date Filing Date Title
EP00610072A EP1172525A1 (fr) 2000-07-12 2000-07-12 Méthode de rénovation de centrales à turbine et chaudière et centrales renovées à turbine et chaudière

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EP1172525A1 true EP1172525A1 (fr) 2002-01-16

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Cited By (13)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP1553274A2 (fr) * 2004-01-09 2005-07-13 Hitachi, Ltd. Rénovation d'une centrale à vapeur comprenant l'addition d'une turbine à gaz et méthode pour le remaniement de l'installation
WO2008034540A1 (fr) * 2006-09-19 2008-03-27 Bayerische Motoren Werke Aktiengesellschaft Systéme d'échangeur de chaleur
WO2010135486A3 (fr) * 2009-05-21 2011-02-24 Mtu Detroit Diesel, Inc. Système de génération de puissance et procédé d'assemblage associé
CN102840594A (zh) * 2011-06-20 2012-12-26 上海机易电站设备有限公司 烟气干燥褐煤中速磨直吹式制粉系统
CN102840593A (zh) * 2011-06-20 2012-12-26 上海机易电站设备有限公司 烟气干燥褐煤中速磨制粉系统
CN102889606A (zh) * 2011-07-20 2013-01-23 上海机易电站设备有限公司 烟气预干燥褐煤钢球磨直吹式制粉系统
CN102889609A (zh) * 2011-07-20 2013-01-23 上海机易电站设备有限公司 烟气干燥褐煤钢球磨制粉系统
CN103486604A (zh) * 2013-09-02 2014-01-01 中冶南方工程技术有限公司 一种干燥介质的生成方法及其系统
EP2065570A3 (fr) * 2007-11-12 2015-09-30 Korea Institute of Energy Research Brûleur pour générer une atmosphère réductrice de gaz d'échappement dans une installation de cogénération de moteur dotée d'un procédé de dénitrification
EP2686525A4 (fr) * 2011-03-18 2015-11-25 Robert P Benz Centrale à production combinée
US9550412B2 (en) 2009-05-21 2017-01-24 Mtu America Inc. Power generation system and method for assembling the same
CN108843428A (zh) * 2018-06-01 2018-11-20 西安交通大学 基于贫氧燃烧催化氧化的分布式燃气能源利用系统及方法
CN111720178A (zh) * 2020-06-11 2020-09-29 浙江浙能技术研究院有限公司 一种基于供电煤耗和投资收益率关联性的燃煤发电机组冷端优化统计分析方法

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JPS62206320A (ja) * 1986-03-06 1987-09-10 Nippon Steel Corp 燃焼炉の空燃比制御装置
JPS6422328A (en) 1987-07-18 1989-01-25 Mitsubishi Heavy Ind Ltd Diesel cogeneration system
US4928635A (en) 1989-07-20 1990-05-29 Mack Shelor Power plant and method of retrofitting existing power plants
JPH07239977A (ja) 1994-02-25 1995-09-12 Tec Corp 商品販売登録データ処理装置
WO1999023360A2 (fr) 1997-10-31 1999-05-14 Wartsila Nsd North America, Inc. Procede d'exploitation d'une centrale electrique a cycle mixte

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* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4492559A (en) * 1983-11-14 1985-01-08 The Babcock & Wilcox Company System for controlling combustibles and O2 in the flue gases from combustion processes
JPS62206320A (ja) * 1986-03-06 1987-09-10 Nippon Steel Corp 燃焼炉の空燃比制御装置
JPS6422328A (en) 1987-07-18 1989-01-25 Mitsubishi Heavy Ind Ltd Diesel cogeneration system
US4928635A (en) 1989-07-20 1990-05-29 Mack Shelor Power plant and method of retrofitting existing power plants
JPH07239977A (ja) 1994-02-25 1995-09-12 Tec Corp 商品販売登録データ処理装置
WO1999023360A2 (fr) 1997-10-31 1999-05-14 Wartsila Nsd North America, Inc. Procede d'exploitation d'une centrale electrique a cycle mixte

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HOELY F - J: "LEISTUNGSSTEIGERUNG FOSSILBEFEUERTER DAMPFTKRAFTWERKE DURCH UMBAU ZU KOMBINIERTEN ANLAGEN", BWK BRENNSTOFF WARME KRAFT,DE,VDI VERLAG GMBH. DUSSELDORF, vol. 48, no. 10, 1 October 1996 (1996-10-01), pages 44 - 48, XP000633032, ISSN: 0006-9612 *
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Cited By (21)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP1553274A2 (fr) * 2004-01-09 2005-07-13 Hitachi, Ltd. Rénovation d'une centrale à vapeur comprenant l'addition d'une turbine à gaz et méthode pour le remaniement de l'installation
EP1553274A3 (fr) * 2004-01-09 2005-11-02 Hitachi, Ltd. Rénovation d'une centrale à vapeur comprenant l'addition d'une turbine à gaz et méthode pour le remaniement de l'installation
WO2008034540A1 (fr) * 2006-09-19 2008-03-27 Bayerische Motoren Werke Aktiengesellschaft Systéme d'échangeur de chaleur
EP2065570A3 (fr) * 2007-11-12 2015-09-30 Korea Institute of Energy Research Brûleur pour générer une atmosphère réductrice de gaz d'échappement dans une installation de cogénération de moteur dotée d'un procédé de dénitrification
WO2010135486A3 (fr) * 2009-05-21 2011-02-24 Mtu Detroit Diesel, Inc. Système de génération de puissance et procédé d'assemblage associé
US8167062B2 (en) 2009-05-21 2012-05-01 Tognum America Inc. Power generation system and method for assembling the same
US9550412B2 (en) 2009-05-21 2017-01-24 Mtu America Inc. Power generation system and method for assembling the same
US8925660B2 (en) 2009-05-21 2015-01-06 Mtu America Inc. Power generation system and method for assembling the same
US8490726B2 (en) 2009-05-21 2013-07-23 Tognum America Inc. Power generation system and method for assembling the same
EP2686525A4 (fr) * 2011-03-18 2015-11-25 Robert P Benz Centrale à production combinée
CN102840593B (zh) * 2011-06-20 2015-04-01 上海援梦电力能源科技咨询中心 烟气干燥褐煤中速磨制粉系统
CN102840594B (zh) * 2011-06-20 2015-04-01 上海援梦电力能源科技咨询中心 烟气干燥褐煤中速磨直吹式制粉系统
CN102840593A (zh) * 2011-06-20 2012-12-26 上海机易电站设备有限公司 烟气干燥褐煤中速磨制粉系统
CN102840594A (zh) * 2011-06-20 2012-12-26 上海机易电站设备有限公司 烟气干燥褐煤中速磨直吹式制粉系统
CN102889609A (zh) * 2011-07-20 2013-01-23 上海机易电站设备有限公司 烟气干燥褐煤钢球磨制粉系统
CN102889609B (zh) * 2011-07-20 2016-03-16 上海援梦电力能源科技咨询中心 烟气干燥褐煤钢球磨制粉系统
CN102889606A (zh) * 2011-07-20 2013-01-23 上海机易电站设备有限公司 烟气预干燥褐煤钢球磨直吹式制粉系统
CN103486604A (zh) * 2013-09-02 2014-01-01 中冶南方工程技术有限公司 一种干燥介质的生成方法及其系统
CN103486604B (zh) * 2013-09-02 2015-11-18 中冶南方工程技术有限公司 一种干燥介质的生成方法及其系统
CN108843428A (zh) * 2018-06-01 2018-11-20 西安交通大学 基于贫氧燃烧催化氧化的分布式燃气能源利用系统及方法
CN111720178A (zh) * 2020-06-11 2020-09-29 浙江浙能技术研究院有限公司 一种基于供电煤耗和投资收益率关联性的燃煤发电机组冷端优化统计分析方法

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