AU2012244230B2 - Process and system for gasification with in-situ tar removal - Google Patents

Abstract

The present invention relates to a process and system for gasifying biomass or other carbonaceous feedstocks in an indirectly heated gasifier and 5 provides a method for the elimination of condensable organic materials (tars) from the resulting product gas with an integrated tar removal step. More specifically, this tar removal step utilizes the circulating heat carrier to crack the organics and produce additional product gas. As a benefit of the above process, and because the heat carrier circulates through alternating steam and oxidizing 10 zones in the process, deactivation of the cracking reactions is eliminated.

Description

AUSTRALIA Regulation 3.2 Patents Act 1990 Complete Specification Standard Patent APPLICANT: Taylor Biomass Energy, LLC Invention Title: PROCESS AND SYSTEM FOR GASIFICATION WITH IN-SITU TAR REMOVAL The following statement is a full description of this invention, including the best method of performing it known to me: PROCESS AND SYSTEM FOR GASIFICATION WITH IN-SITU TAR REMOVAL CROSS REFERENCE TO RELATED APPLICATIONS 5 This application claims priority from US Provisional App. Ser. No. 60/728,989, filed October 21, 2005, the entire contents of which are herein incorporated by reference. 10 BACKGROUND OF THE INVENTION 1. Field of the Invention The present invention relates to a process and system for gasifying 15 biomass or other carbonaceous feedstocks in an indirectly heated gasifier and a method for the elimination of condensable organic materials (tars) from the resulting product gas with an integrated tar removal step. More specifically this integral tar removal step utilities the circulating heat carrier to crack the organics and produce additional product gas. As a benefit of the above process and 20 because the heat carrier circulates through alternating steam and oxidizing zones in the process, deactivation of the cracking reactions is eliminated.

2. Description of the Related Art The related art involves a biomass gasification system and method as described in US Pat. No. 6,808,543 (Paisley), the contents of which are 5 incorporated herein fully by reference (also referred to as the FERCO system). The '543 patent proves a gasification method involving a circulating fluidized bed (CFB) gasifier system wherein sand is used as a heat transfer medium. A first aspect of the system provides a method for reducing ash agglomeration in a parallel entrainment fluidized bed gasifier/combustion 10 wherein Magnesium Oxide (MgO) is added into the thermal transfer material to alter a eutectic of the resultant ash and thereby raise a melting point of such ash to minimize agglomeration with the sand. In this way the '543 patent teaches the need to minimize sand+ash agglomeration through an increase of the ash melting point by adding MgO. Paisley '543 distinguishes itself from prior systems 15 adding CaO and A1 2 0 3 in attempts to reduce agglomeration by diluting ash. The related art also involves a method for hot gas conditioning as described in US Pat. No. 5,494,653 (Paisley), the contents of which are also incorporated herein fully by references. The '653 patent discusses the production of a feed gas for hydrogen 20 synthesis using gasification in a fluidized bed reactor (FBR), recirculating fluidized bed reactor (CFB), or in a fixed bed reactor (FB), and requires the use of a catalyst to adjust the hydrogen to carbon monoxide ratio in a water gas shift reaction, 25 Equation I CO+ H20 =C02+ H2 2 in such a way as to not promote the formation of carbon, an undesired byproduct. Patent '653 teaches that alumina is a preferred catalyst and that conventional catalyst systems and methods for such reactions require the use of noble metals such as nickel, molybdenum, and the like, or of alkali materials such as 5 potassium, sodium, and the like for catalysts. Further, conventional catalyst systems and methods do not suppress carbon to the extent desired in the '653 patent. Typical of these and other gas production operations are the following U.S. Pat. Nos. 233,861 to Jerzmanowski; 1,295,825 to Ellis; 1,875,923 to Harrison; 1,903,845 to Wilcox; 1,977,684 to Lucke; 1,992,909 to Davis; 10 2,405,395 to Bahlke et al; 2,546,606; 3,922,337 to Campbell et al; 4,726,913 to Brophy et al; 4,888,131 to Goetsch et al; 5,143,647 to Say et al; and British patent GB 461,402 (Feb. 16, 1937). The '653 patent teaches a method of cracking and shifting a synthesis gas by providing a catalyst consisting essentially of alumina in an out-of-the-re 15 circulating-path chamber; and contacting the alumina catalyst with a substantially oxygen free synthesis gas of methane and/or higher molecular weight hydrocarbons; and water vapor at a temperature of about 530*C to about 980'C, whereby methane and higher hydrocarbons are cracked according to the reaction, 20 Equation 2 CH 2 y + xH 2 O = xCO + (1 +y+x)H 2 and shifted by the reaction in Equation 1 (water gas shift reaction), whereby carbon formation is minimized at temperatures below 980'C. 3 As a consequence, the '653 patent teaches the use of alumina as a gas conditioning catalyst that can shift the so called water gas shift reaction to enable a ratio of H 2 :CO of 2:1. While the mechanical system in the '653 patent is generally similar to 5 that in the '543 patent, a difference exists for the above-noted out-of-cycle (ex situ) lower temperature reaction chamber (maximum 980*C/1500"F) that receives an output synthesis gas from the gasification module and contains the alumina catalyst for down-stream reaction. As a consequence, the '653 patent differs from that of the '543 system by providing both (i) an alumina (A120 3 ) 10 catalyst and (ii) providing that catalyst only in an ex situ chamber of low temperature that results in rapid downstream deactivation of the cracking reactions due to the deposition of carbon on the catalyst surface. These related art references fail to appreciate a number of aspects noted in the present invention. These aspects include the use of a re-circulating heat 15 transfer medium containing a catalyst, the removal of hydrocarbons (condensables) at high temperatures above about 370'C, and the removal of condensables in an in situ process (continuous removal with recycle). As a consequence, a number of aspects of the present invention are not appreciated by the prior art. These include the ability of the present invention to 20 recover heat at a significantly lower temperature following an in situ condensable removal step (due to the removal of tars from the gas at high temperature). Similarly, the related art fails to appreciate the benefit of a separate gas conditioning module that is heated in situ at high system temperatures 25 (1000 0 C/1800 0 F) by a thermal transfer medium heated in a combustor module 4 and recycles for continuous use, thereby increasing the efficiency of all reactions due to higher temperature use. Furthermore, the related art fails to appreciate the ability for increased hydrogen (H2) recovery by including an in situ gas-conditioning module that 5 operates at system high temperatures. Finally, the related art in all cases fails to appreciate the use of steam in situ as a reactive to impact the water gas shift reaction in gas conditioning and thereby minimize the requirement for removal of condensables in a separate (ex situ) and costly downstream process 10 Accordingly, there is a need for an improved process that enables removal of condensable products in situ and which therefore enables, but does not require, an improved energy recovery from product gas. The reference to any prior art in this specification is not, and should not be taken as an acknowledgement or any form of suggestion that the referenced 15 prior art forms part of the common general knowledge in Australia. OBJECTS AND SUMMARY OF THE INVENTION An object of the present invention is to provide a process for gasification 20 with in-situ tar removal that responds to at least one of the needs noted above without a requirement of responding to more than one of the needs noted above or to provide an alternative to the prior art. The present invention relates to a process and system for gasifying biomass or other carbonaceous feed stocks in an indirectly heated gasifier and 25 provides a method for the elimination of condensable organic materials (tars) from the resulting product gas with an integrated tar removal step. More 5 specifically, this tar removal step utilizes the circulating heat carrier to crack the organics and produce additional product gas. As a benefit of the above process, and because the heat carrier circulates through alternating steam and oxidizing zones in the process, deactivation of the cracking reactions is eliminated. 5 Unlike other know biomass gasification processes, the presently provided process is not based on starved air combustion, but instead rather rapidly heats raw biomass in an air free environment to minimize tar formation and create a solid residue that is used as a heat source for the process. Significantly fewer emissions are produced in the process because of the relative ease of treating the 10 high energy density, medium calorific value gaseous resultant product. In the process, biomass is indirectly heated using a heat transfer material (preferably sand) to produce a medium calorific value gas (approximately 17-19 MJ/Nm 3 /350-450 Btu/scf) as shown in Fig. 1. In the process a circulating heat transfer material is used to rapidly heat 15 incoming biomass and convey unconverted material from the gasification reactor to an associated reactor. In the gasifier, heated heat transfer materials (sand) and steam contact the biomass. No air or oxygen is added so there are no combustion reactions taking place, providing an environmental advantage. The biomass is rapidly converted into medium calorific gas at a temperature of approximately 20 825*C (Celsius). Any unconverted material along with the now cooled heat transfer materials (sand), pass through the gasifier and then are separated from the product gas. The heat carrier materials and char formed in the gasifier are conveyed to the process combustor. In the combustor, air is introduced which in turn 25 consumes the char in combustion and, in the process, reheats the heat carrier (sand) to approximately 1000 0 C. In the combustor all remaining carbon is 6 consumed, resulting in substantially carbon-free ash suitable for environmentally friendly and inexpensive disposal. Due to the combustor conditions and the fact that the unconverted material is essentially carbon, emissions are desirably low from this step in the process. The reheated heat transfer solids are thereafter 5 separated from the flue gas and returned to the gasifier. Ash is removed from the flue gas, resulting in a high temperature (approximately 1000'C) clean gas stream, available for heat recovery. The product gas exiting the gasifier is conveyed through a gas conditioning reactor prior to final cleanup. In this cracking reactor, the product 10 gas is heated to approximately 1000 C (1832 0 F), the temperature of the heat transfer material returning to the gasification reactor from the combustion reactor, noted above. At 1000 0 C, the condensable hydrocarbons (tars) are cracked to form lower molecular weight compounds such as hydrogen (H2), Carbon Monoxide (CO), Benzene (C 6

H

6 ), and Methane (CH4). This cracking 15 step eliminates higher molecular weight materials from the gas thus substantially simplifying downstream heat recovery and final gas clean up for particulate material. Furthermore, the present invention provides for the further production of increased hydrogen using the adjustment of the hydrogen:carbon monoxide ratio by an in situ water gas shift reaction as noted in Equation 1. 20 As an additional benefit of the present invention, by removing condensable from the product gas, enhanced heat recovery is possible. When condensables remain in the product gas, the product gas may only be cooled to approximately 370'C during heat recovery. After condensable removal however, heat recovery may occur at least as low as 200'C resulting in 25 approximately a 40% improvement in recovered energy from the product gas. 7 By suitable selection of the circulating heat transfer materials, and the inclusion of a catalytically active material, the product gas may be further chemically adjusted providing water gas shift potential for (a) chemical synthesis, (b) hydrogen production applications or (c) adjusting chemical 5 compositions for specific downstream uses. According to one alternative aspect of the present invention, a method is provided for converting a synthesis gas containing hydrocarbons, the method comprising the steps of: providing both an indirectly heated gasification module for generating the synthesis gas from a carbonaceous fuel, and a combustion 10 module for contributing to an operation temperature of the gasification module, providing an in situ gas conditioning module for receiving the synthesis gas from the gasification module and for operating at the operation temperature, and in the gas conditioning module, conditioning the synthesis gas to minimize a tar content therein. 15 According to another alternative aspect of the present invention, a system is provided for gasification with in-situ conditioning, comprising: a gasification module for gasifying a biomass feedstock into the synthesis gas, a gas conditioning module for receiving the synthesis gas from the gasification module and for conditioning the synthesis gas in an in situ circuit with the gasification 20 module and a combustion module, and the combustion module for heating a thermal transfer material and for circulating the heated thermal transfer material to the gas conditioning module before circulating the thermal transfer materials to the gasification module. According to another alternative aspect of the present invention, a system 25 is provided for gasification with in-situ conditioning, the system comprising: an indirectly heated gasification module means for generating the synthesis gas 8 from a carbonaceous fuel, and a combustion module means for contributing to an operation temperature of the gasification module, in situ gas conditioning module means for receiving the synthesis gas from the gasification module and for operating at the operation temperature, and in the gas conditioning module 5 means, means for conditioning the synthesis gas to minimize a tar content therein. According to another alternative aspect of the invention, an apparatus for conditioning a synthesis gas containing hydrocarbons, comprising: an indirectly heated gasification module for generating the synthesis gas from a carbonaceous 10 fuel, and a combustion module means for contributing to an operation temperature of the gasification module, in situ gas conditioning module for receiving the synthesis gas from the gasification module and for operating at the operation temperature, and the conditioning module including a module for conditioning the synthesis gas to minimize a tar content therein comprising a 15 system for cracking the hydrocarbons and shifting the synthesis gas, thereby producing a conditioned gas containing a hydrogen:carbon monoxide ratio having a positive hydrogen balance. The above, and other objects, features and advantages of the present invention will become apparent from the following description read in 20 conduction with the accompanying drawings, in which like reference numerals designate the same elements. In the specification the term "comprising" shall be understood to have a broad meaning similar to the term "including" and will be understood to imply the inclusion of a stated integer or step or group of integers or steps but not the 25 exclusion of any other integer or step or group of integers or steps. This definition also applies to variations on the term "comprising" such as "comprise" 9 and "comprises." BRIEF DESCRIPTION OF THE DRAWINGS 5 Fig. I is a pictographic flow diagram of the system according to the present invention. Fig. 2 is a detailed process flow diagram of one alternative and preferred embodiment of the present invention. Fig. 3 is a graph of a Mass Spectrometry result showing the hydrocarbon 10 analysis results before entering the gas-conditioning module of the present invention. Fig. 4 is a graph of a Mass Spectrometry result showing the hydrocarbon analysis results of syngas upon exiting the gas-conditioning module of the present invention noting the substantive reducing of hydrocarbon. 15 Fig. 5 is a graphical representation of the effect of the water gas shift in the present gas-conditioning reactor wherein the "negative" component (for hydrogen, CO 2 , and CO) depicts the formation of more of the component and the "positive" component for the remaining hydrocarbons depicts their reduction. Fig. 6 is a graph representing the conversion of condensable 20 hydrocarbons according to the present invention achieving over 95% conversion of some tars and 80% conversion of problem tars. DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS 25 Reference will now be made in detail to several embodiments of the invention that are illustrated in the accompanying drawings. Wherever possible, 10 same or similar reference numerals are used in the drawings and the description to refer to the same or like parts or steps. The drawings are in simplified form and are not to precise scale. For purposes of convenience and clarity only, directional terms, such as top, bottom, up, down, over, above, and below may be 5 used with respect to the drawings. These and similar directional terms should not be construed to limit the scope of the invention in any manner. The words "connect," "couple," and similar terms with their inflectional morphemes do not necessarily denote direct and immediate connections, but also include connections through mediate elements or devices. 10 Referring now to Fig. 1 a schematic flow process of the present system is provided for gasifying biomass or other carbonaceous feed stocks in an indirectly heated gasifier that eliminates condensable organic materials (hydrocarbons/tars) from the resulting product gas with an integrated tar removal step. More specifically, this tar removal step utilizes the circulating heat carrier to crack the 15 organics and produce additional product gas in combination with a water gas shift reaction as will be discussed. As a benefit of the proposed process, and because the heat carrier circulates in situ through alternating steam and oxidizing zones in the process, deactivation of the cracking reactions is eliminated. Unlike other know biomass gasification processes, the presently provided 20 process is not based on starved air combustion, but instead rather rapidly heats raw biomass provided at a feedstock preparation and feed supply module 100 in an air free environment within a sealed gasification reactor 102 to minimize tar formation and create a solid residue (char) that is used as a heat source for the process within combustion reactor 105. Significantly fewer emissions are 25 produced in the process because of the relative ease of treating the high energy density, medium calorific value gaseous resultant product. In the process, 11 biomass is indirectly heated using a heat transfer material (preferably sand) to produce a medium calorific value gas (syngas) having approximately 17-19 MJ/Nm 3 /350-450 Btu/scf from a gas-conditioning reactor 103 pulled for synthesis or turbine or fuel use at 104. 5 In the process (discussed in more detail in Fig. 2) circulating heat transfer material is used to rapidly heat incoming biomass and convey unconverted material from the gasification reactor to an associated reactor. In gasifier 102, heated heat transfer materials and steam 101 are contacted in a sealed system. No air or oxygen is added so there are no combustion reactions taking place, 10 providing an environmental advantage. The biomass is rapidly converted into medium calorific gas at a temperature of approximately 825*C (Celsius) or above. Any unconverted material (char) along with the now cooled heat transfer materials (sand), pass through the gasifier and then are separated from the product gas. 15 The heat carrier materials and char formed in the gasifier are conveyed to process combustor 105 for combustion and reheating. In the combustor 105, air is introduced which in turn consumes the char in combustion and, in the process, reheats the heat transfer carrier to approximately 1000'C. In combustor 105 all remaining carbon is consumed, resulting in substantially carbon-free ash suitable 20 for environmentally friendly and inexpensive disposal at 106. Due to the combustor conditions and the fact that the unconverted material is essentially carbon, emissions are desirably low from this step in the process. The reheated heat transfer solids are thereafter separated from the flue gas and returned to the gasifier 102. Ash is removed from the flue gas, resulting in a high temperature 25 (approximately 1000*C) clean gas stream that may also be employed for a heat recovery process 107. 12 The product gas exiting the gasifier is conveyed through an in situ gas conditioning reactor prior to final cleanup. In the gas conditioning reaction a cracking function occurs as the product gas is heated to approximately 1000 0 C (1832*F), the temperature of the heat transfer material returning to the 5 gasification reactor from the combustion reactor, noted above. At 1000'C (well above the related art references), the condensable hydrocarbons (tars) are reacted with steam inputs and cracked to form lower molecular weight compounds such as hydrogen (H 2 ), Carbon Monoxide (CO), Benzene (C 6

H

6 ), and Methane (CH 4 ). This cracking step eliminates higher molecular weight materials from the gas 10 thus substantially simplifying downstream heat recovery and final gas clean up for particulate material. As an additional benefit of the present invention, by removing condensables from the product gas, enhanced heat recovery is possible without detrimental tar condensation. When condensables remain in the product gas, the 15 product gas may only be cooled to approximately 370'C during heat recovery. After condensable removal however, heat recovery may occur to at least as low as 200'C resulting in approximately a 40% improvement in recovered energy from the product gas. Referring now to Fig. 2 a more detailed gasifier system I is provided 20 according to the present invention and generally includes a gasifier module 12 in fluid communication with a combustion module 32 which operate cooperatively to convert biomass inputted via process feed P1 into syngas, char, and heat. Process feed P1 operates to condition and supply biomass feed stocks and includes a biomass fuel stream including commonly recognized biomass fuels 25 such as construction and demolition materials, organic debris, and other biomass subject matter known to those of skill in the art. Biomass stream PI is delivered 13 into storage module 4 containing a feeding mechanism (as shown) driven by a motor 10 and input for an inert gas such as nitrogen or argon via valve 6. A fugitive dust collector system 2 retains delivery fines and delivers the same to module 4 via rotary valve 3 or other mechanical means. The live storage 5 module 4 delivers feed stock via rotary valve 7 supplied with inert gas via valve 6 to a fuel metering system 8 containing a screw conveyor 9 driven by a motor 10, as shown, and supplied with an inert gas via valve 6. It should be recognized that biomass stream P1 may also contain a variety of precursor preparation modules including a moisture control module or dryer, 10 storage bins modules, pre-combustors modules and/or chemical pre-treating modules as will be known to those of skill in the biomass preparation arts. Process feed P2 delivers the prepared feed stock material to gasifier 12 which subjects the same to heat by contacting it with a heat transfer medium in an oxygen free environment, partially or wholly volatilizing the feed stock 15 material to release a mixture of gasses including H 2 , CO, CO 2 , CH 4 , C 6

H

6 and other carbonaceous gases and tars as noted herein. Gasification reactor or module 12 is heated via heating feed P1 1 with a hot heat transfer medium such as sand or other inert and/or chemically active solid material and gas fluidized material from combustion module 32 via a gas 20 conditioning reactor 20, as will be discussed. Gasification module 12 can be of any conventional type known to those of skill in the art without limitation, such as a perforated plate type gas distributor used commonly in fluidized bed systems. As a consequence, gasification module 12 is shown with a distributor 12, and inputs of steam S via valve control 6 and an inert gas G also via a control 25 valve 6. 14 In the preferred embodiment noted steps are taken to ensure an entirety of the bed is fluidized thereby minimizing incomplete circulation and that the inner constructions of gasification module 12, combustion module 32, and related high temperature system components are construction of a substantially non-reactive 5 material. Gasifier 12 operates as a circulating fluidized bed gasifier so that char formed during gasification retains the general geometric form of the feedstock and is circulated with syngas out an exit port via pathway 3 to gas conditioning reactor 20. Between pathway 3 and gas conditioning reactor 20 is an optional 10 gasification reactor surge module 15 containing a reactor separator 14 (including a cyclone) and an associated fluidizing distributor 16 receiving inputs of steam and inert gas as shown to maintain flow. Separator 14 operates to separate sand and char directly to an input port of combustion module 32 via feed P5. As shown a syngas pathway P4 is shown noting the transfer of syngas from surge 15 module 15 directly to an input on gas conditioning reactor 20. Syngas pathway P4 is augmented with a steam input controlled by a control valve 6, as shown, and the syngas comprises at least CO and H2 as well as a variety of other gasses (and tars) in concentrations and combinations dependent upon the reaction within gasification reactor 12. As a consequence of 20 the input of steam to gas conditioning reactor 20 there is truly a reaction occurring within this in situ module, here the water gas shift reaction and other reactions involving the cracking of petrochemical molecules. Upon receiving syngas and tar flow via flow path P4 at operating temperature and distributed by a distributor 19, gas conditioning module 20 25 operates to crack the tars and balance the water shift reaction to create syngas (synthesis gas) containing up to 50% H2 and as little as about 0.0003 lb/cft 15 (pounds per cubic foot) of residual tar both limits far exceeding the related references. While not required by the present invention, conditioning reactor module 20 may further include an optional combustion reactor separation 22 for 5 receiving ash and further non-convertible particles and transferring the same via a feed flow P9 to an ash separator 23 for distribution as flue gas via pathway P12 and as non-consumable ash via pathway P13 to an ash handling system 24 in operative communication with an ash dust collector 25 (for fines) and an ash collector 26 (for solids) for later distribution. 10 In the preferred embodiment shown, an exit of combustion reactor 32 provides heated heat transfer materials via a flow path P7 to combustion reactor 22 and gas-conditioning module 20. As a consequence, gas-conditioning module 20 is maintained at high operation temperatures up to about 1000 0 C. In the preferred embodiment shown, an additional surge module 18 receives heated 15 heat transfer materials from gas conditioning module 20, ensures fluidization of the same with an inert gas feed via a flow valve 6 to a distributor 7, and may similarly receive a reactant such as steam via an additional flow valve 6, as shown. Syngas that has completed conditioning in conditioning module 20 is 20 removed via feed line P8 as product gas, as will be discussed. As noted, feed flow P5 transports char and heat transfer materials to an input port of combustion module 32 for further combustion and reheating as necessary. Combustion module 32 receives heat via a distributor mechanism 31 from a natural gas combustion system, controlled by a valve 6 and combustion 25 air supply A via a combustion blower 29 fed via a volume control 30 to a start up and maintenance heater 28 that combusts the natural gas and feeds the combined 16 combustion gases via feed P6 to distributor 31 in combustion module 32. As a consequence of a combination of such a heat input via feed P6 together with the further combustion of the recovered char in combustion module 32 (thereby completing its reaction) the temperature of the heat transfer materials fed to gas 5 conditioning module 20 via flow P7 is maintained and enhanced as needed for process control. After heating in gas conditioning module 20, heat transfer materials are transferred via flow PlO to gasification module 12 via surge module 18, as shown. Recognizing that heat transfer materials may need to be added to the 10 continuously operating system, a heat transfer medium make-up module 27 operating via feed P14 may be operated to maintain or augment heat transfer materials and add catalyst materials as required by operators of system 1. Following entry of the same into combustion module 32 they are fluidized and join the fluidized flow materials within system 1 and exit the top of combustor 15 32 as flue gas. Similarly, recognizing gas may not always be used downstream, and as an optional safety feature, following operation of gas conditioning module 20, system I includes an optional flare stack 21 accessible via a flow valve 6 from the exit flow P8 of product gas so as to provide a control combustion mechanism 20 where the resultant syngas may not be otherwise employed downstream for materials manufacturing, fuel cell synthesis, fuel generation, and pre-use or pre shipment storage. As a consequence of the above discussion, the present disclosure shall recognize that the use of gasification reactor surge module 15, return surge 25 module 18 and the associated pathways, distributors, and separators are optional to the present embodiment that requires only the use of gas conditioning reactor 17 module 20. Similarly, without respective surge modules 15, 18, return flows P3/P4 may combine to directly supply exit heat transfer materials, syngas and tars from the exit port at the top of gasification module 12 to gas conditioning reactor 20 (in a flow similar to that shown in Fig. 1). In a related discussion, 5 absent surge modules 15, 18 return heat transfer materials may return from an exit portal at the top of combustion module 32 through gas conditioning reactor 20 directly to an input portal in gasification reactor 12. As a consequence of the above paragraph, those of skill in the art will recognize that the flow process depicted in Fig. I is a preferred embodiment according to the present invention 10 and that the detailed depiction in Fig. 2 is an additional (and optional) further preferred embodiment. Referring now to Figs. 3 and 4, the present process flow diagram shown in Fig. 2 was tested by sampling the synthesis gas (resultant gas) from flow P3 exiting gasification module 12 and before entry of gas conditioning module 20 15 (shown as Fig. 3) and from flow P8 exiting gas conditioning module 20 (Fig. 4). Both are shown as Mass Spectrometry results with peaks noting the various hydrocarbon chains. As will be obvious to those of skill in the art, Fig. 3 notes both a substantial volume of high molecular weight hydrocarbons (above the Benzene 20 peak 78), and a high volume of lower molecular weight hydrocarbons (below the Benzene peak 78). Following gas conditioning in gas conditioning reactor 20, Fig. 4 notes the beneficial results of both reduced volume of total hydrocarbons of all molecular weights and the substantial shift of molecular weights to those hydrocarbons having generally lighter molecular weights (less than say the 25 Benzene peak 78) that may be easily removed by downstream processes should any remain. As an additional benefit of the present invention, the post gas 18 conditioning hydrocarbons are more predictably segmented and arranged and hence may be more readily retrieved by tailor-able downstream processes such as secondary ex situ elected solvent treatment, electrostatic precipitators, scrubbers, and other methods known to those of skill in the art. 5 As discussed herein, the preferred gasifier process system 1, includes an in situ gas conditioning module 20 operating at system temperature and producing significantly more hydrogen through the water gas shift reaction, Equation 3 CO + H20 = C02 + H2 10 due to the catalytic action of the heated solids in the gas conditioning reactor. Measured gas composition compared to other known gasification processes are shown below (dry basis) in Table I. 15 19 Table I TABLE I Gasifier Gas, VoL % Taylor' FERCO2 FICFBi Thermochem 4 H2 43.8 20.7 37.7 52.2 CO 25.4 46 26.2 38.4 CH4 10.7 15.6 9.9 1.8 C02 19.1 11.1 20.3 7.4 C2H4 0.7 5.3 2.5 0.2 C2H6 0 0.7 0.2 0.1 N2 0.9 0.6 3.2 0 Tars (lb/cft) -0.0003 0.025 0.003 Not reported in pounds per literature cubic foot__ From the system as shown 2 From http://www.fercoenterprises.com for discussion of the FERCO-gasifier 5 results From http://www.ficfb.at/ discussion of the FICFB-gasifier results From www.thermochem.net discussion of the Kirk Othmer Encyclopedia of Chemical Technology Information, "Biomass Energy" by M. Paisley, pub John Wiley & Sons 2002. 10 As a consequence, to provide the water necessary for the water gas shift reaction, sufficient steam must be available in the gas entering the gas conditioning step. This is accomplished by increasing the steam flow to the gasification module 20 (either via increasing the steam flow to the gasification 15 module (an indirectly supply) or to the gas conditioning module via steam input to process flow P4 (a direct supply) or both). Graphically, the effect of the water 20 gas shift is in the table at Fig. 5. As noted in the graph, "conversion" is defined as the decrease of a component in the gas, so a negative conversion indicates the formation of more of the component. A major advantage of the gas conditioning reactor in the present 5 invention is the substantive removal of the condensable hydrocarbons in the gasifier product gas in an in situ step without relying on complex downstream cracking steps. As shown above in Table 1, significantly smaller quantities of these "tars" are present in the gas exiting the Taylor gasifier than are found in other indirectly heated gasifiers. This simplifies both final gas cleanup and heat io recovery. The result is (1) a higher efficiency process as additional heat recovery is possible (to temperatures as low as 200*C), and (2) a more economical process (as the costly removal of the condensables in a separate downstream process step is minimized or eliminated). It similarly should be noted that the nitrogen (N2) identified within the Taylor and Ferco systems is likely simply the result of 15 minor purge nitrogen introduced initially into the stream. As a consequence, it is simple to contrast the poor results in Hydrogen (H 2 ) of the Ferco system with that of the system described herein (more than double). It should be similarly noted, that by adjusting the water gas shift reaction in the present in situ reaction system 1, the CO 2 concentration may provide additional Hydrogen exceeding 20 50%. As noted in the related art, a separate (ex situ), downstream catalyst reactor required for later hydrocarbon conversion depends on maintaining the catalyst activity at a high level so that the condensables can be cracked. At the temperature usually used for this (i.e. the gasifier temperature of 760*C/1400*F 25 to 816 0 C/1500 0 F) this is materially difficult and costly as the cracking reactions tend to form free carbon, which subsequently deactivate the catalyst and slow the 21 system requiring re-supply of fresh catalyst. In the preferred configuration shown, the cracking reactions take place at a much higher temperatures (900*C/1652'F to 1 100 C/2012'F) that unknown in the related art and within the circulating system itself (in situ) thereby reducing 5 the potential to form carbon. As a further advantage, by using the heat carrying/heat transfer medium as the in situ catalytic agent, any carbon that might form is consumed in the combustor module prior to being recycled to the gas conditioning reactor thereby further "regenerating" the material to maintain high catalyst activity levels. 10 Referring now to Fig. 6, a figure illustrating the conversion of the condensable hydrocarbons occurring within the in situ gas conditioning reactor such that the conversion of total tar is nearly 80%, the conversion of so called heavy or high molecular weight tar exceeds 82%, the conversion of all other tars exceeds 80%, and the conversion of hydrocarbons (Toluene, Phenol, Cresol) 15 exceeds 90% with a corresponding increase in the volume of benzene (C 6

H

6 ) that may be readily addressed by known processes. In considering both Figs. 5 and 6, those of skill in the art will consider the additional details shown below in Tables 2 and 3 to further support the present discussion. Specifically, table 2 below shows the detailed concentration data for 20 the condensables, and table 3 shows the same data but expanded to provide detail for specific compounds. 22 Table 2 TABLE 2 Results Species Inlet Outlet % (mg/Nm conversionn Benzene 7123 6703 (41.3) Toluene 3596 158 93.4 Phenol 2376 99 93.7 Cresol 1206 26 T 96.7 Naphthalene 2105 1561 (11.4)1 Anth/Phen 518 298 13.7 Other Tar 12648 1632 80.6 Heavy Tar 5775 623 83.8 "Total 28223 4397 78.0 Tar" 23 TABLE 3 TABLE3 Molecular Formula Chemical Name(s) % Weight conversion 15,16 CH 4 methane (30.6) 26 C 2

H

2 acetylene 58.3 78 C 6

H

6 benzene (41.3) 91,92 C 7

H

8 toluene 93.4 94 CJHLO phenol 93.7 104 CgH8 styrene 93.4 106 C 8 Hio (m-, o-, p-) xylene 97.3 108 C 7

H

8 0 (m-, o-, p-) cresol 96.7 116 C 9

H

8 indene 93.8 118 C 9 Ho indan 98.4 128 CioH 8 naphthalene (11.4) 142 C 11 Hio (1-, 2-) methylnaphthalene 97.1 152 C 12

H

8 acenapthylene 402 154 C 12

H

10 acenaphthene 72.3 166 C1Hio fluorene 89.0 178 C 14

H

10 anthracene, phenanthrene 13.7 192 C 15

H

1 2 (methyl-) 99.3 anthracenes/phenanthrenes 202 C 16 HIO pyrene/fluoranthene (19.6) 216 C 17

H

12 methylpyrenes/benzofluorenes 92.3 228 C 18 H 12 chrysene, benz[a]anthracene, 24.4 242 C 1 9 1-1 1 4 methylchrysenes, 90.5 ethylbenz[a]anthracenes 252 C 20

H

12 perylene, benzo[a]pyrene, 16.7 266 C 21

H

14 dibenz[akl]anthracene, 92.7 278 C 22

H

1 4 dibenz[ah]anthracene, 45.5 5 In considering the above, it will be noted that regeneration of the heat transfer material was tested by passing air through the material after several 24 hours of operation (significantly longer exposure to the product gas than would be the case in expected normal operation). During normal operation, the solids would be recycled after approximately 8 to 15 minutes. Both cracking results and water gas shift results before and after regeneration were identical. 5 In the system of one of the preferred embodiments of the present invention, the bed of heat transfer material at the lower end of the gasifier module 12. As the biomass is contacted by the heat transfer material and hot gas, it is pyrolized (gasified) and an entrained region of heat transfer material, char and carbonaceous particles forms in the upper end of gasifier module 12. 10 Entrained heat transfer materials circulate through the entrained biomass, char, and hot gases. As the carbonaceous particles pyrolyze, they generate gas forming a relatively higher velocity region above the fluidized bed. As depicted and discussed, in system 1 pyrolized solids are removed from the top of combustion reactor 12 for transport to either gas conditioning module 15 20 or combustion module 32 following separation, and removed from the system by entrainment despite the low inlet gas velocities below the bed. This is made possible by the design of using a fluidized region, above which is an entrained region from which all bed particles including inerts and char are removed. Thus, entrainment occurs in part because of the gas generated in situ contributing 20 significantly to the volume of gas moving through the reaction vessel for later conditioning in gas conditioning module 20, while avoiding destructive slugging. The carbonaceous biomass materials fed to gasifier module 12 may achieve greater than 60% conversion of the available carbon upon a single pass through the gasifier system 1 due to the present invention's ability to operate at 25 temperatures above 980'C. The remainder of the carbon is burned in combustion module 32 to generate heat for the pyrolysis reaction upon recycle. If other fuel 25 is used in combustion module 32, then additional carbon can be converted in the gasifier module 12. With wet fuels, such as municipal waste, carbon conversions might vary upward or downward depending on the operating temperature of the gasifier module 12 and consequently the preferred embodiment provides a series 5 of pre-feed conditioning (and drying) steps before feeding via flow P2. The inlet gas fed to gasifier module 12 typically can be steam (as shown), recycled-product-gas and inert gases such as nitrogen, argon, and mixtures thereof Preferred gases for the invention are steam and recycled-product-gas, and most preferably steam and inert gases. 10 In this invention entrained material exits the gasification module 12 near the top and is passed through (the product synthesis gas) to the gas-conditioning module 20, and the solids (the char, carbonaceous material, and heat transfer materials) are returned to the combustion reactor module 32 for combustion and heating respectively. All system solids are entrained except for unwanted tramp 15 material such as scrap metal inadvertently introduced with the fuel feedstock, for which a separate cleanout provision may be needed. The system of the present invention is versatile and could be combined with any type of combustor, fluidized, entrained, or non-fluidized, for heating the heat transfer material. The heat transfer material is heated by passage through an 20 exothermic reaction zone ofthe combustion module 32 to add heat. As a consequence of the above, those of skill in the art will recognized the improvements provided herein; which include the use of an in-situ gas conditioning module, the use of a re-circulating phase having a catalytic feature or operation in its process, the use of steam in a gas-conditioning module as a 25 reactant, the operational resultant ratio of H 2 :CO of about 2:1 or higher thereby 26 minimizing a need for subsequent modification (positive ratio regarding hydrogen). Finally, it is recognized that for the generation of free hydrogen (H2) we are using in situ gas synthesis instead of some form of petrochemical reaction 5 such as a subsequent water gas synthesis. Beneficial products produced by the above described system include a gas with such a highly favorable Hydrogen:Carbon Monoxide ratio that it may be useful as a gasoline additive, or in fuel-cell synthesis, or in power production typically for a combined cycle gas turbine power generation system. 10 As noted above, while the present system generates up to and above 50% hydrogen which may be used directly, subsequent steps for hydrogen recovery may be used and these may optionally include; the common membrane separation process based on partial pressure or a second level or later process water-gas shift reaction. 15 As used herein, the phrase inert material is understood to mean relatively inert (relatively non-reactive) as compared to the rapidly reactive carbonaceous material and may include heat transfer materials such as sand, limestone, and other calcites or oxides. As noted more fully, some of these heat transfer materials may not be relatively inert and may otherwise participate as reactants 20 or catalytic agents, thus "relatively inert" is used as a comparison to the carbonaceous materials and is not used herein in a strict or pure qualitative chemical sense as commonly applied to the noble gases. For example, in coal gasification, limestone is useful as a means for capturing sulfur to reduce sulfate emissions and is thus active in cracking the tar in gasification reactor 12 and gas 25 conditioning module 20, but as used herein shall be relatively inert. 27 While one benefit of the presently disclosed system is substantial minimization of agglomeration due to the high temperature operating conditions and in situ gas conditioning reactor 20, other useful materials may also be added to the gasifier feedstock to further improve system operation and further enhance 5 the generation of ready-to-use end gases removed from gas conditioning reactor 20. For example, it has been found that the agglomeration of ash, sand, and char in gasifier system I can be further reduced by adding of magnesium oxide (MgO), Olivine, or other Fe-surface containing compositions to the in situ heat transfer materials and optionally the feedstock materials. Since the 10 conventionally known agglomeration is generally a result of the partial-melting of the ash at high temperature condensation, minimizing such high temperature condensation and restricting the original creation of provide substantive benefits. In prior systems, calcium oxide (CaO) and alumina (A1 2 0 3 ) have been added in an attempt to reduce agglomeration of ex situ ash by diluting the ash, and the US 15 Pat. No. 6,808,543 (lacking any form of in situ gas conditioning module) teaches that the addition of MgO is even more effective to reduce agglomeration by reducing the eutectic of the ex situ ash mixture and hence raising the melting point to effectively reduce agglomeration at a weight percent or between 1% and 25% of the feedstock weight. 20 However, in contrast to the teachings of the '543 patent, any other related reference the present invention provides for the use of an in situ Olivine catalyst material within the range of 1-50% by weight of the heat transfer materials and even more preferably between 2% and 40% of a catalytically active material is added to the in situ heat transfer material to reduce aggregation (via origination 25 prevention, conversion, and elimination) and promote catalysis in accordance with the present invention. 28 As used herein the phrases heat transfer medium or heat transfer materials shall not be viewed by those of skill in the art as being restricted to sand or olivine, but shall instead by considered to include all inorganic solids capable of at least temporarily resisting thermal breakdown at temperatures of up 5 to I 100*C/2012*F. As a consequence, such heat transfer materials shall not be viewed exclusively as to the materials noted herein, but rather inclusively, and as such may include (without limitation or exclusion) catalytically active materials and non-catalytically active materials, common sand (quartz or otherwise), olivine, silica (SiO 2 or SiO 4 ), alumina (A1 2 0 3 ), feldspar, and other metal oxides 10 (including MgO, CaOy, ZnOx, ZrOx, TiOx, B 2 0 3 ), and multiple combinations and compositions involving the same, including those that are partially or wholly stabilized, previously sintered or otherwise thermally prepared, and which may be naturally occurring or artificially formed. Those of skill in the art shall consider as used herein catalytically active 15 heat transfer materials shall be recognized as catalytically active materials and include, but not be limited to all of those heat transfer materials above that exhibit decomposition activity of hydrocarbons; including treated and untreated Dolomite and treated and untreated olivine, and alumina (both naturally occurring and artificially formed types, and either treated with calcination or 20 other methods), alkali metal oxides, noble metal oxides, Ni-based compositions (including Ni/ A1 2 0 3 , NiCuMo/SiO 2 or SiO 4

-AI

2 0 3 ), Mg-based oxides, Fe-based oxides, Ca-oxides, V-based oxides, Cr- based oxides, Co-oxides, Cu-oxides, Mo oxides, calcined dolomites, magnesites, zeolites, and high-temperature oxide compositions containing elements of the above. 25 As used herein, the phrase iron transport catalyst shall be understood to include, but not be limited to, those catalytically active heat transfer material 29 noted above that contain iron as well as other iron-containing ceramic materials and compositions, including natural and artificially formed olivine. Similarly, as will be understood by those of skill in the art, the use of the phrase in situ shall be recognized and referring to as an in-process activity or a 5 process, such as gas conditioning, that occurs in a circulating fluid path between a gasification reactor and a combustion reactor, and not as a separate external process beyond the system. For example here, gas conditioning module 20 is "in situ" because it receives thermal transfer materials from both combustion module and syngas from gasification module.. 10 In the claims, means- or step-plus-function clauses are intended to cover the structures and reactions described or suggested herein as performing the recited function or reaction and not only structural and chemical equivalents but also equivalent structures and compositions. Thus, for example, although a nail, a screw, and a bolt may not be structural equivalents in that a nail relies on 15 friction between a wooden part and a cylindrical surface, a screw's helical surface positively engages the wooden part, and a bolt's head and nut compress opposite sides of a wooden part, in the environment of fastening wooden parts, a nail, a screw, and a bolt may be readily understood by those skilled in the art as equivalent structures. In a similar manner, the phrase catalytically active 20 materials include those materials functioning as catalysts. Having described at least one of the preferred embodiments of the present invention with reference to the accompanying drawings, it is to be understood that the invention is not limited to those precise embodiments, and that various changes, modifications, and adaptations may be effected therein by one skilled in 25 the art without departing from the scope or spirit of the invention as defined in the appended claims. 30

Claims (22)

1. A method of gasifying a biomass feedstock, comprising: providing both an indirectly heated gasification module for generating a 5 synthesis gas from a carbonaceous fuel, and a combustion module for contributing to an operation temperature of said gasification module; providing an in situ gas conditioning module for receiving said synthesis gas from said gasification module and for operating at said operation temperature; and in said gas conditioning module; 10 conditioning said synthesis gas to minimize a tar content therein; providing a heat transfer material containing at least a first portion by weight of a catalytically active heat transfer material; contacting said heat transfer material with said synthesis gas in said gas conditioning module thereby enabling said step of conditioning; and 15 circulating said heat transfer material from said combustion module where said heat transfer material is heated to maintain an operation temperature, to said gas conditioning module where at least said step of contacting occurs at said operation temperature, and to said gasification module where said synthesis gas is generated from said feedstock as said carbonaceous fuel. 20

2. The method according to claim 1, wherein the operation temperature is about 1000*C/1800*F.

3. The method according to claim I or 2, wherein said step of conditioning results in the production of one or more lower molecular weight compounds.

4. The method according to claim 3, wherein said one or more compounds 25 are hydrogen, carbon monoxide, benzene and methane.

5. The method according to any one of claims 1 to 4, wherein higher 31 molecular weight compounds are eliminated.

6. The method according to any one of claims I to 5, wherein said feedstock is converted to synthesis gas, char and heat.

7. The method according to any one of claims I to 6, wherein said feedstock 5 comprises a biomass fuel stream.

8. The method according to claim 7, wherein said stream comprises one or more biomass fuels.

9. The method according to claim 8, wherein said one or more biomass fuels are selected from the group comprising construction materials, demolition 1o materials and organic debris.

10. An apparatus when used to gasify a biomass feedstock, comprising: an indirectly heated gasification module for generating a synthesis gas from a carbonaceous fuel; a combustion module for contributing to an operation temperature of said 15 gasification module; an in situ gas conditioning module for receiving said synthesis gas from said gasification module and for operating at said operation temperature; and in said gas conditioning module, wherein said synthesis gas is conditioned to minimize a tar content therein; 20 a heat transfer material containing at least a first portion by weight of a catalytically active heat transfer material wherein said heat transfer material is contacted with said synthesis gas in said gas conditioning module thereby enabling said step of conditioning; and circulating said heat transfer material from said combustion module 25 where said heat transfer material is heated to maintain an operation temperature, to said gas conditioning module where at least said step of contacting occurs at 32 said operation temperature, and to said gasification module where said synthesis gas is generated from said feedstock as said carbonaceous fuel.

I1. The apparatus of claim 10, wherein the operation temperature is about 1000 0 C/18000F. 5

12. The apparatus of claim 10 or 11, wherein said step of conditioning results in the production of one or more lower molecular weight compounds.

13. The apparatus of claim 12, wherein said one or more compounds are hydrogen, carbon monoxide, benzene and methane.

14. The apparatus of any one of claims 10 to 13, wherein higher molecular 10 weight compounds are eliminated.

15. The apparatus of any one of claims 10 to 14, wherein said feedstock is converted to synthesis gas, char and heat.

16. The apparatus of any one of claims 10 to 15, wherein said feedstock comprises a biomass fuel stream. 15

17. The apparatus of claim 16, wherein said stream comprises one or more biomass fuels.

18. The apparatus of claim 17, wherein said one or more biomass fuels are selected from the group comprising construction materials, demolition materials and organic debris. 20

19. An apparatus, comprising: a biomass stream; a gasification module for generating a synthesis gas from a carbonaceous fuel; a combustion module for contributing to an operation temperature of said 25 gasification module; a heat transfer material containing at least a first portion by weight of a 33 catalytically active heat transfer material; an in situ gas conditioning module; and an operation temperature of about IOOOC/l800'F.

20. The apparatus of any one of claims 10 to 19, further comprising one or 5 more of the following: combustion reactor separators, ash separators, dust collectors, ash collectors, and combustion blowers.

21. The apparatus of claim 17 or 19, wherein said stream comprises one or more precursor preparation modules.

22. The apparatus of claim 21, wherein said one or more precursor 10 preparation modules comprise one or more of the following: moisture control modules; storage bin modules; pre-combustor modules and chemical pre-treating modules. 34