EP0105874A1 - Installation de production d'energie - Google Patents

Installation de production d'energie

Info

Publication number
EP0105874A1
EP0105874A1 EP19820901675 EP82901675A EP0105874A1 EP 0105874 A1 EP0105874 A1 EP 0105874A1 EP 19820901675 EP19820901675 EP 19820901675 EP 82901675 A EP82901675 A EP 82901675A EP 0105874 A1 EP0105874 A1 EP 0105874A1
Authority
EP
European Patent Office
Prior art keywords
combustion
combustor
products
air
inlet
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Withdrawn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
EP19820901675
Other languages
German (de)
English (en)
Inventor
Andrew B. Baardson
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Individual
Original Assignee
Individual
Priority date (The priority date 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 date listed.)
Filing date
Publication date
Application filed by Individual filed Critical Individual
Publication of EP0105874A1 publication Critical patent/EP0105874A1/fr
Withdrawn legal-status Critical Current

Links

Classifications

    • 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
    • F02—COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
    • F02C—GAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
    • F02C1/00—Gas-turbine plants characterised by the use of hot gases or unheated pressurised gases, as the working fluid
    • F02C1/04—Gas-turbine plants characterised by the use of hot gases or unheated pressurised gases, as the working fluid the working fluid being heated indirectly
    • F02C1/05—Gas-turbine plants characterised by the use of hot gases or unheated pressurised gases, as the working fluid the working fluid being heated indirectly characterised by the type or source of heat, e.g. using nuclear or solar energy
    • F02C1/06—Gas-turbine plants characterised by the use of hot gases or unheated pressurised gases, as the working fluid the working fluid being heated indirectly characterised by the type or source of heat, e.g. using nuclear or solar energy using reheated exhaust gas

Definitions

  • This invention relates generally to power plants. More specifically, the invention relates to an improved heat source for use in indirect gas turbine power plants.
  • biomass is intended to define any type of combustible plant material, including organic fibrous materials such as sewer sludge.
  • wood wastes defines wood materials such as bark, shavings, trimmings, chips, sawdust, hog fuel, and the like which are typically by-products of various operations performed at a lumber mill. Biomass, coal and wood wastes are typically in particulate form when they are to be used as fuel in a suspension burner.
  • Nettel also includes a second heat exchanger positioned remote from the combustion chamber in an attempt to absorb additional heat from the products of combustion leaving the combustion chamber.
  • products of combustion as used herein is intended to cover not only the exhaust gases which result from combustion of fuel, but also gaseous combustibles in the form of vapors which may emanate from liquid or solid fuels, and air, which, for various reasons, has not been used up in combustion. Nettel also suggests that the products of combustion might be combined with hot air exhausted from the turbine to form a stream which is then fed back to the combustion chamber as combustion air.
  • Nettel's system is undoubtedly more efficient than some other designs, he overlooks the fact that the fuel is not going to be completely burned in his single combustion chamber. For example, as noted above, combustible (and therefore energy-containing) gases will typically be emitted with the exhaust gases from this combustion chamber. Therefore, Nettel's system inherently wastes fuel which will eventually pass to the atmosphere with the other products of combustion.
  • a second drawback with Nettel's system is that he positions a heat exchanger within his primary combustion chamber. This requires the use of exotic and therefore expensive materials since the heat exchanger will be subjected to extremely high temperatures.
  • the present invention overcomes these disadvantages in "Nettel's and other prior art systems by providing a unique arrangement of a secondary combustion chamber having a heat exchanger therein.
  • the use of secondary combustion chambers per se is not new.
  • my earlier U.S. Patent No. 3,831,535 discloses a so-called blending chamber which receives products of combustion from a primary combustion chamber, and continues to burn those products of combustion along with recirculated volatile fumes which provide additional fuel to the blending chamber.
  • my system disclosed in my aforementioned patent ' nor any other prior systems, include the unique features found in the present invention which permit greater efficiency than previously thought possible.
  • Another object is to provide a power plant system wherein temperatures throughout the system are easily controllable in order to maximize the efficiency of the system and to maintain the desired output temperatures and pressures.
  • Yet another object is the provision of a system in which the primary combustion chamber is maintained at an optimum temperature for a more complete combustion of particulate fuels.
  • Another object is to utilize energy derived from the combustion of wood wastes and other fuels to generate electricity using a conventional gas turbine, air to air heat exchanger, and electrical generator.
  • a more specific object is to provide a power plant system especially adapted for optimum, utilization of the potential heat energy from the combustible wood wastes of a lumber or plywood mill to generate electricity for powering both in-plant and out-of-plant apparatus.
  • This invention responds to the problems presented in the prior art by providing an indirect gas turbine power plant having primary and secondary combustors wherein fuel is burned and heat is conveyed to a turbine working medium which is subsequently passed through the turbine section of a gas turbine.
  • the gas turbine includes both a ' compressor section and a turbine section.
  • the primary combustor has a first inlet for receiving exhaust air from the turbine section, a second inlet for receiving fuel and an outlet for discharge of products of combustion.
  • the secondary combustor includes a first inlet for receiving at
  • a gas-to-gas heat exchanger hereinafter referred to as an air heat exchanger, is positioned within the secondary combustor.
  • This heat exchanger includes an inlet for receiving compressed air from the compressor section of the gas turbine, heat exchange surface means for conveying heat from the products of combustion to the compressed, air, and an outlet to direct the compressed, hot air out of the secondary combustor for passage to the turbine section of the gas turbine.
  • First conduit means are also included for conveying a portion of the products of combustion from he secondary combustor outlet to the second inlet of the secondary combustor.
  • This first conduit may, if desired, direct the secondary combustor products of combustion through a boiler or other heat use before conveying the products of combustion back to the secondary combustor.
  • the first conduit may be adapted to receive other energy inputs such as hot exhaust air or other gases which would be combined with the secondary combustor products of combustion prior to reinjection back into the secondary combustor.
  • the invention also normally includes a boiler having inlet means for receiving hot gases which include exhaust air from the turbine section of the gas turbine and the products of combustion of the secondary combustor, outlet means for discharging the hot gases, and steam generation means for conveying heat from the hot gases to
  • the compressed, hot air which is discharged from the secondary combustor air heat exhanger can be directed to energy absorption means which would use a portion of the energy contained in such air and pass the remainder to the primary combustor for use as combustion air, to a boiler, or to both the primary combustor and a boiler.
  • energy absorption means might typically comprise a dehydrator for food processing and the like, a glass production facility, or any other use which requires substantial amounts of heat energy.
  • the air compressor would be driven by other means.
  • FIGURE 1 is a schematic drawing of a first embodiment of the present invention.
  • FIGURE 2 is a schematic drawing of a second embodiment of the present invention.
  • FIG. 1 is merely a schematic of the system, showing the flow of fluids through the power plant 10.
  • the system includes a primary combustor 12, a secondary combustor 14 and a gas turbine 16.
  • the gas turbine 16 includes a turbine section 18 and a compressor section 20, and is adapted to provide a power drive for any conventional use.
  • gas turbine 16 is drivingly connected to a first electrical generator 22.
  • the power plant 10 also normally includes a boiler system 24.
  • This boiler system 24 includes a boiler 26 which provides steam to drive a steam turbine 28.
  • the steam turbine 28 is, in turn, drivingly connected to a second electrical generator 30.
  • a steam condenser 32 is included in the boiler system 24 in order to recover and condense the steam.
  • the working fluid for primary turbine 16 is air, and therefore power plant 10 can be described as an indirect system. As discussed previously, this distinguishes it from a direct system in which products of combustion actually pass through gas turbine 16 as the working fluid.
  • the power plant thus has the capability of utilizing low-grade parti ⁇ ulate or .other fuels.
  • Figure 1 includes a plurality of letters identifying various points in the power plant 10. These letters will be used in Chart A below to identify the conditions of the fluids in the system at these points. Chart a lists specific heat (Sp) , temperature (° C), mass flow (kilogram per hour), and Btu. In the ensuing discussion, reference will be made only to the temperature of the fluid, but the remainder of the conditions can be ascertained by reference to Chart A. It should be appreciated that these values are based upon theoretical calculations, and in actual practice may be somewhat different than the listed values.
  • the power plant depicted in Figure 1 includes a combustion air blower 34 which receives exhaust air from gas turbine 16 via an exhaust air conduit 36, and directs this air into primary combustor 12.
  • This exhaust air is under pressure and is heated to approximately 424° C. (see Position A in Chart A). Therefore, it will increase the efficiency of combustion in primary combustor 12 and will provide excess air to support combustion in the secondary combustor 14.
  • combustion air is preferably directed into primary combustor 12 at two points along its length, i.e., one adjacent a burner 44, and the other in the vicinity of the other end of primary combustor 12. one way to do this is to provide an annular jacket
  • IJUR (not shown) surrounding primary combustor 12 with apertures therein leading into the primary combustor to permit combustion air to flow therethrough at the desired points.
  • Combustion air is thus directed into primary combustor 12 in a radial direction from several aligned apertures positioned around the periphery of the primary combustor.
  • This arrangement provides an adequate amount of air at- the burner 44, thus resulting in a highly efficient, lean flame without producing ash or other by-products, and also serves to prevent excessive temperatures in the primary combustor. This is desirable in order to prevent the formation of silica within primary combustor 12 and to prevent excessive temperatures in secondary combustor 14 for purposes to be described hereinbelow.
  • combustion air is introduced in this fashion, it has been found that the use of 100 to 200% excess air provides for particularly efficient combustion in both the primary and secondary combustors.
  • the temperature in primary combustor 12 is typically 1316° C., although it may be lower under some operating conditions.
  • the 1316° C. reading is based upon a fuel feed of 4400 pounds (1980 kg) of particulate wood waste, conveyed in an airstream at ambient temperature.
  • the combustion taking place in secondary combustor 14 is that of the combustible vapors and gases produced during the burning of the particulate fuel in primary combustor 12. That is, the particulates themselves are normally fully burned in primary combustor 12.
  • the combustor of the particulate fuel results in the rendering of substantial amounts of gaseous combustibles. These combustibles begin to burn immediately as they are produced, and continue to burn as they pass into the secondary combustor 14.
  • the gaseous combustibles are mixed with products of combustion which have been recirculated from a secondary combustor discharge conduit 38 via a recirculation conduit 40 and a recirculation blower 41.
  • the secondary combustor products of combustion may, in certain systems, be utilized elsewhere prior to being recirculated back to secondary combustor 14.
  • hot exhaust air and/or gases from elsewhere in the system may be directed into recirculation conduit 40 upstream of the secondary combustor to utilize any heat in such gases and to burn any gaseous combustibles contained therein.
  • the second basic reason for recirculating secondary combustor products of combustion is to lower the temperature of the products of combustion emanating from primary combustor 12 which, as previously indicated, may be as hot as 1316° C. A lower temperature is desirable because an air heat exchanger 42 is positioned within secondary combustor 14. Subjecting the air heat exchanger 42 to temperatures approximating 1316° C. would tend to shorten its life unless it were made of special, high-temperature, exotic materials which would be prohibitively expensive.
  • the third reason for recirculating secondary combustor products of combustion is to make further use of the heat contained within those gases.
  • the air heat exchanger is schematically depicted in Figure 1 as comprising a plurality of helically disposed tubes which generally define a cylinder through which the products of combustion are directed.
  • the air heat exchanger 42 may, however, be of any other conventional design which maximizes transfer of heat from the products of combustion to the air passing through the air heat exchanger.
  • Air heat exchanger 42 is adapted to receive compressed (and therefore heated) air from the compressor section 20 of the gas turbine 16 via a compressed air conduit 46. As indicated at Position D on Chart A, air passing through compressed air conduit 46 into air heat exchanger 42 is at 316° C. The air is discharged from air heat exchanger 42 through a hot air conduit 48 at 871° C. (see Position E) . These readings are based upon an ambient air intake at compressor section 20 of 910 cubic meters per minute at 15° C.
  • first electrical generator 22 puts out 2630 kilowatts (kw) thus providing a first energy output from power plant 10.
  • secondary combustor discharge conduit 38 be well insulated. It may be desirable
  • Boiler 26 is of the water-tube type adapted to generate steam by conveying heat from the previously-mentioned hot gases to water in the boiler tubes. Under the indicated conditions boiler 26 typically operates at 300 psi (20.8 kg per square cm), producing 21,564 pounds (9704 kg) of steam per hour having 1202 Btu per pound (2644 Btu per kg) . This steam is directed through a steam outlet conduit 52 to steam turbine 2.8 which drives second electrical generator 30. Under these conditions, the steam turbine can be expected to operate at 61% efficiency, producing 945 kw from second electrical generator 30. This thus provides a second energy output from power plant 10. The steam from second electrical generator
  • condenser 32 where the steam is condensed.
  • the steam may be directed to other stations for further use prior to condensation.
  • the condensate is pumped back into boiler 26 by a feed pump 54. At this point the condensate typically contains 196 Btu per pound.
  • the hot gases (made up of turbine exhaust air and products of combustion) which are discharged form boiler 26 through boiler discharge conduit 56 are still at a temperature of about 149° C. (see Position K) . Therefore, they are still usable for any conventional purpose. For example, if power plant 10 is being utilized in a lumber mill, these gases may be fed to a rotary drier (not shown) where wood is dried. Thus, a third energy output is provided by the power plant.
  • blowers 34 and 41 and pump 54 serve to control the flow of fluids through power plant 10 to maximize efficiency of the system.
  • a second embodiment of the present invention is schematically depicted in Figure 2. Since many of the components of this second embodiment correspond to components in the previously-described power plant 10, corresponding numerals will be used to designate the system in Figure 2, except that the numeral 1 will be added to each designation.
  • the system generally is identified with the numeral 110.
  • Power plant 110 includes a primary combustor 112, a secondary combustor 114, and a gas turbine 116.
  • the gas turbine 116 includes a turbine section 118 and a compressor section 120 and is adapted to provide power drive for conventional uses, such as the generation of electricity. Therefore, a first electrical generator 122 is depicted in Figure 2.
  • Power plant 110 also normally includes a boiler system 124 having a boiler 126 which provides steam to drive a steam turbine 128. The steam turbine is drivingly connected to a second electrical generator 130.
  • a steam condenser 132 is included in the boiler system 124 to complete the system.
  • power plant 110 is an indirect system utilizing a turbine working fluid, here air, to convey energy from the fuel to gas turbine 116.
  • Chart B lists theoretical conditions of the fluids in power plant 110 in the same fashion as described previously with respect to power plant 10.
  • Power plant 110 includes a combustion air blower 134 which provides combustion air to primary combustor 112.
  • a conduit 136 leads from turbine section 118 of gas turbine 116 to the inlet of combustion air blower 134 so that the hot exhaust air from the turbine is blown into primary combustor 112.
  • the exhaust air is typically at a temperature of 377° C. (see Position A) , thereby increasing the efficiency of combustion in primary combustor 112.
  • Combustion air is introduced into primary combustor 112 in the same fashion as described with respect to power plant 10; that is, at two points along its length, one adjacent a burner 144 and the other adjacent secondary combustor 114.
  • annular jacket (not shown) is preferably utilized so that combustion air can be directed into primary combustor 112 in a radial direction from a plurality of aligned apertures positioned around the periphery of the primary combustor.
  • 100 to 200% excess air provides for paritcularly efficient combustion in both the primary and secondary combustors. It should be appreciated, however, that under certain conditions it may be desirable to use a greater or lesser amount of excess air.
  • the particulate fuel is fully burned in primary combustor 112. This combustion, in combination with the excess air, supports combustion of the gaseous combustibles which have been rendered from the particuate fuel.
  • the primary combustor typically can be fed at a rate of 5365 pounds (2414 kg) of fuel per hour. This feed rate provides a primary combustor temperature of 1316° C. (see Position B) .
  • exhaust air and/or gases from elsewhere in the system may be directed into recirculation conduit 140 upstream of the secondary combustor to utilize any heat in such gases and to burn any gaseous combustibles contained therein.
  • the depicted air heat exchanger 142 is of conventional design, utilizing a plurality of U-shaped tubes to provide the desired number of passes. It should be understood, however, that it may be desirable in some applications to utilize any other conventional design such as the helical-shaped tubes shown in Figure 1.
  • the air heat exchanger 142 receives compressed air from compressor section 120 of gas turbine 116 via a compressed air conduit 146. As noted at Position D, this compressed air will typically be heated to 310° C. during compression, based upon an ambient air intake at the compressor 910 cubic meters per minute at 15° C.
  • the compressed, hot air is directed to turbine section 118 of gas turbine 116 via hot air conduit 148. As indicated at Position E, this air is normally at 788° C.
  • the air Upon entering the gas turbine 116 the air impinges upon turbine blades, thereby driving the gas turbine and the first electrical generator 122 mounted thereto. This typically generates 2100 kw, thus providing a first energy output from power plant 110.
  • Turbine air discharge conduit 150 directs the exhaust air from gas turbine 116 toward boiler 126. While this air is expanded, it still typically retains a temperature of 377° C. (see Position F) . As previously discussed, a portion of the exhaust air passes through air conduit 136 to provide excess combustion air to primary combustor 112. The remainder of the exhaust air is sent to boiler 126 via turbine air discharge 150, which converges with the secondary combustor discharge conduit 136 conveying products of combustion from secondary combustor 114. As previously discussed in connection with power plant 10, these products of combustion include only very small amounts of gaseous combustibles, virtually all of these gases being burned in secondary combustor 114. At this point (identified by Position H) the products of combustion are at 502° C. When the exhaust air from gas turbine 116 and the products of combustion from secondary combustor 114 merge, the resulting hot gases are at 458° C. (see Position J) .
  • Boiler 126 like boiler 26 of power plant 10, is of conventional water-tube type, adapted to generate steam at 400 psi (27.7 kg per square cm) by conveying heat from the hot gases (comprised of turbine exhaust air and products of combustion) to water in the boiler tubes. Boiler 126 typically
  • OM produces 26,774 pounds (12,048 kg) of steam per hour with 1362 Btu per pound (2996.4 Btu per kg).
  • This steam is directed through a steam outlet conduit 152 to steam turbine 128.
  • the steam turbine 128 typically operates at an efficiency of 65% and drives the second electrical generator 130, normally producing 2556 kw. This provies a second energy outlet from the power plant 110.
  • the steam from steam turbine 128 is subsequently directed to condenser 132 where the steam is condensed.
  • the steam may be directed to other stations for further use prior to condensation.
  • the condensate containing 196 Btu per pound (431 Btu per kg) , is pumped back into boiler 126 by a feed pump 154.
  • a portion of the hot gases passing through boiler discharge conduit 156 is directed to recirculation conduit 140 which, as previously discussed, conveys these gases back to secondary combustor 114.
  • the remaining hot gases discharged from the boiler (which are at 177° C. as indicated at Position K) may be utilized for other purposes such as the drying of wood products.
  • a third energy output is provided from power plant 110. it may be desirable to position a blower
  • blowers 134 and 141 and pump 154 serve to control the flow of fluids ' through power plant 110 to maximize efficiency of the system.
  • O- ⁇ (not shown), such as those previously described, may be substituted for the turbine section depicted in power plants 10 and 110 of the drawings.
  • compressor 20 or 120 would be driven by other means, such as steam turbine 28 or 128, or any other engine.
  • electrical generator 22 or 122 would normally also be deleted. In all other respects the power plant would operate substantially as described hereinabove.

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  • Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Physics & Mathematics (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • High Energy & Nuclear Physics (AREA)
  • Sustainable Development (AREA)
  • Sustainable Energy (AREA)
  • Engine Equipment That Uses Special Cycles (AREA)

Abstract

Une installation de production d'énergie à turbine à gaz indirecte comprend des chambres de combustion primaire et secondaire (12 et 14) dans lesquelles le combustible est brûlé et la chaleur est amenée à un milieu de travail dans la turbine qui traverse par la suite la partie de turbine d'une turbine à gaz. La turbine à gaz (16) comprend une partie compresseur (20) et une partie turbine (18). La chambre de combustion primaire (12) possède un premier orifice d'admission (36) recevant l'air s'échappant de la partie turbine, un deuxième orifice d'admission (44) recevant le combustible et un orifice de sortie pour la décharge des produits de combustion. La chambre de combustion secondaire (14) comprend un premier orifice d'admission recevant au moins une partie des produits de combustion sortant de la chambre de combustion primaire, un deuxième orifice d'admission recevant une partie des produits de combustion de la combustion secondaire et un orifice de sortie pour la décharge des produits de combustion de la chambre de combustion secondaire. Un échangeur thermique à air (42) servant à transmettre la chaleur dégagée par les produits de combustion à l'air comprimé est positionnée à l'intérieur de la chambre de combustion secondaire. Cet échangeur thermique comprend un orifice d'admission (46) recevant l'air comprimé provenant de la partie compresseur de la turbine à gaz et un orifice de sortie (48) pour diriger l'air chaud comprimé à l'extérieur de la chambre de combustion secondaire et vers la partie turbine.
EP19820901675 1982-04-16 1982-04-16 Installation de production d'energie Withdrawn EP0105874A1 (fr)

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
PCT/US1982/000477 WO1983003636A1 (fr) 1982-04-16 1982-04-16 Installation de production d'energie

Publications (1)

Publication Number Publication Date
EP0105874A1 true EP0105874A1 (fr) 1984-04-25

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Family Applications (1)

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EP19820901675 Withdrawn EP0105874A1 (fr) 1982-04-16 1982-04-16 Installation de production d'energie

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EP (1) EP0105874A1 (fr)
AU (1) AU8459282A (fr)
WO (1) WO1983003636A1 (fr)

Families Citing this family (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6747734B1 (en) 2000-07-08 2004-06-08 Semitool, Inc. Apparatus and method for processing a microelectronic workpiece using metrology
AT501504B1 (de) * 2005-03-07 2009-05-15 Walter Ing Falkinger Wirkungsgradsteigerung bei kohle- und biomassekraftwerken
EP2405106A1 (fr) * 2010-07-06 2012-01-11 Sib Siber S.p.A. Centrale électrique alimentée à la biomasse

Family Cites Families (3)

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Publication number Priority date Publication date Assignee Title
DE842876C (de) * 1942-03-19 1952-07-03 Oerlikon Maschf Dampf-Luft-Waermekraftanlage
DE839290C (de) * 1944-01-05 1952-05-19 Oerlikon Maschf Dampf-Gas-Waermekraftanlage
US3831535A (en) * 1973-11-02 1974-08-27 Mill Conversion Contractor Inc Wood waste burner system

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
See references of WO8303636A1 *

Also Published As

Publication number Publication date
WO1983003636A1 (fr) 1983-10-27
AU8459282A (en) 1983-11-04

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