Enhancement of Fischer-Tropsch process for hydrocarbon fuel formulation

Abstract

An enhanced Fischer-Tropsch process for the synthesis of sulfur free, clean burning, green hydrocarbon fuels, examples of which include syndiesel and aviation fuel. Naphtha is destroyed in a hydrogen generator and recycled as feedstock to a syngas (FT) reactor in order to enhance the production of syndiesel from the reactor. A further variation integrates a second hydrogen generator capturing light hydrocarbon gas for conversion to hydrogen and carbon monoxide which supplements the Fischer-Tropsch reactor. The result is a considerable increase in the volume of syndiesel formulated. A system for effecting the process is also characterized in the specification.

Claims

1. A system for synthesizing hydrocarbons, said system comprising: (a) means for generating syngas lean in hydrogen content; (b) means for catalytically converting said syngas to produce hydrocarbons, containing at least naphtha; (c) a hydrogen generator; (d) circuit means for recycling naphtha to said hydrogen generator to form a hydrogen rich stream; and (e) circuit means for combining said hydrogen rich stream with said hydrogen lean stream to provide a blended and enriched hydrogen content stream for enhancing hydrocarbon production.

2. The system as set forth in claim 1, wherein said means for generating syngas comprises a thermal gasifier.

3. The system as set forth in claim 1, wherein said means for catalytically converting said syngas comprises a Fischer-Tropsch reaction.

4. The system as set forth in claim 1, wherein said circuit means for recycling naphtha to said hydrogen generator comprises a recycle loop.

5. The system as set forth in claim 1, wherein said hydrogen generator comprises a member selected from the group consisting of a steam methane reformer and a autothermal reformer or a combination thereof.

6. The system as set forth in claim 1, wherein said circuit means for recycling naphtha to said hydrogen generator comprises a recycle loop for recycling naphtha into at least one of said SMR, said ATR, or a combination thereof.

7. The system as set forth in claim 1, wherein said hydrogen generator comprises an SMR and an ATR.

8. The system as set forth in claim 1, further including means for hydrocracking product exiting said means for catalytically converting said syngas.

9. The system as set forth in claim 1, further including means for fractionating hydrocracked product.

10. The system as set forth in claim 1, further including means for withdrawing energy from said system to act as a precursor for power generation.

11. The system as set forth in claim 1, further including means for storing formulated enhanced hydrocarbon.

Description

BRIEF DESCRIPTION OF THE DRAWINGS

(1) FIG. 1 is a process flow diagram of methodology known in the prior art;

(2) FIG. 2 is a process flow diagram similar to FIG. 1, illustrating a first embodiment of the present invention;

(3) FIG. 3 is a process flow diagram illustrating a further variation of the instant technology;

(4) FIG. 4 is a process flow diagram illustrating yet another variation of the present invention;

(5) FIG. 5 is a process flow diagram of a still further embodiment of the present invention; and

(6) FIG. 6 is a process flow diagram illustrating a still further variation of the present methodology.

(7) Similar numerals employed in the figures denote similar elements.

DETAILED DESCRIPTION OF PREFERRED EMBODIMENTS

(8) Referring now to FIG. 1, shown is a process flow diagram of a circuit for gasifying biomass with the result being the production of naphtha and syndiesel. The process is generally denoted by numeral 10 and begins with a biomass feedstock 12, which feedstock has been described with examples herein previously. The biomass is then treated in a gasifier 14 to which oxygen 16 may be added as required. The gasifier may be any suitable gasifier, however, as an example, a gasifier that is useful in this process is that which has been patented by Choren Industries GmbH. Details of this gasifier and the process for using the gasifier are disclosed in U.S. Pat. No. 7,776,114, issued Aug. 17, 2010, to Rger et al. The Choren gasification process and apparatus has been found to be effective in the methodology of the present invention to be discussed hereinafter. Generally, as is known from the Choren process, the same effectively involves a low temperature pyrolysis stage which is followed by a high temperature gasification stage.

(9) Although the Choren gasifier is a highly eligible process and apparatus for carrying out the instant technology, it will be well appreciated by those skilled in the art that any other suitable gasifier can be integrated into the process without any compromise in performance. Table 1 delineates gasifiers useful for syngas production.

(10) TABLE-US-00001 TABLE 1 Special Gasifiers for Synthesis Gas Production Entrained Blue Tower Carbo V flow gasifier CFB Gasifier FICFB Total system Low temp. Pyrolysis and Circulation Pyrolysis and Fast internal gasifier and entrained flow Fluidized Bed reforming gasification entrained flow gasifier gasifier (CFB) gasifier 1.sup.st stage Low temp. Flash Pyrolysis 550- gasifier at pyrolysis 600 C. 400-600 C. 500 C. Gasifier Autotherm Autotherm Autotherm Autotherm CFB entrained flow entrained flow CFB with reforming with gasification gasifier with 2 gasifier silica sand as ceramic as with 2 zones: zones: ~1300 C. and bed, >900 C., heat carrier, Combustion Combustion >50 bar P.sub.atm 950 C., P.sub.atm with air 1300-1500 C., 970 C., Gasification Gasification 800-900 C. 900 C. P.sub.atm Gasification O.sub.2/air O.sub.2 O.sub.2/H.sub.2O H.sub.2O H.sub.2O Agent Gas cleaning Bag filter, wet Wet scrubber, Hot gas filter unknown Filter, wet scrubber, cooling SO.sub.2- with ceramic, scrubber, SO.sub.2-removal removal wet scrubber, ZnO carbon adsorber, adsorber removal of S and Cl Gas* WGS, WGS, WGS, unknown unknown conditioning CO.sub.2-removal CO.sub.2-removal CO.sub.2-removal Synthesis gas composition (% vol.) after gas cleaning H.sub.2 40.2 (22.1) 27 26.04 53 38-40 CO 39.2 (21.8) 50 29.91 12 22-26 CO.sub.2 20.4 (11.4) 14 33.69 25 20-22 CH.sub.4 0.1 (0) <0.1 8.8 6 9-11 N.sub.2 0.1 (44.7) 6.3 0.17 2 1.2-2 Note: The number in the bracket for Carbo V gasifier is the synthesis gas composition, when air is used as gasification agent. Sources: (1) Henrich, E.and Dinjus, E. 2003 Das FZK-Konzept zur Kraftstoffherstellung aus Biomasse, Der Knigsweg fr eine effiziente Strom-und Kraftstoffbereitstellung, Leipzig; (2) Rauch, R. 2002 Zweibett-Wirbelschichtvergasung in Guessing (A) mit 2 MW.sub.ei/4.5 MW.sub.th; Konzept, Betrieberfahrung und Wirtschaftlichkeit. 7. Holzenergie-Symposium, Zrich. *Optional unit, not required in this application.

(11) As is known, the gasifier is useful for synthesizing a hydrogen lean or deficient synthesis gas (syngas) stream in a non-catalytic partial oxidation reaction. The so formed syngas is then subjected to cleaning operations 18 with subsequent removal of carbon dioxide at 20. It is not preferred in this process to include a water gas shift (WGS) reactor unit prior to the CO.sub.2 removal as all the carbon, primarily as CO is used to the maximum production of synthesis liquids product. The process uses the supplemental addition of hydrogen to maximize the conversion to syndiesel. The raw syngas is treated in various steps of scrubbing units and guard units well known to those skilled in the art to create a relatively pure clean syngas suitable for use in a Fischer-Tropsch unit. The carbon dioxide removal may also include a compression step (not shown) which is optionally attributable to the other processes discussed in forthcoming Figures. The syngas is then transferred to a Fischer-Tropsch reactor 22 to produce the hydrocarbons and water. The so formed hydrocarbons are then passed on to a hydrocarbon cracking stage 24, a product fractionating stage 26 with naphtha being produced at 28 as a fraction, as well as diesel 30 as an additional product. The diesel 30 formulated in this process is commonly known as syndiesel. As an example, this process as is well known in the art, results in the formulation of 701 barrels per day (bbl/day) based on 20 tonnes per hour of forestry biomass. As is illustrated in the flow diagram, an external source of hydrogen 32 is to be supplemented to the Fischer-Tropsch unit 22 and hydrocarbon cracking unit 24 denoted as streams 36 and 34 respectively. Further, energy 35 from the gasifier, typically in the form of steam, may be used to generate power and this is equally true of the Fischer-Tropsch reactor 22 creating energy 40. Table 2 establishes a comparison between FT diesel and conventional petroleum based diesel.

(12) TABLE-US-00002 TABLE 2 Specification of FT-diesel in comparison to conventional diesel Conventional Diesel Fuel Specification FT-Diesel Diesel Chemical formula Paraffin C.sub.12H.sub.26 Molecular weight (kg/kmol) 170-200 Cetane number >74 50 Density (kg/l) at 15 C. 0.78 0.84 Lower Heating Value (MJ/kg) at 15 C. 44.0 42.7 Lower Heating Value (MJ/l) at 15 C. 34.3 35.7 Stoichiometric air/fuel ratio (kg air/kg fuel) 14.53 Oxygen content (% wt) ~0 0-0.6 Kinematic viscosity (mm.sup.2/s) at 20 C. 3.57 4 Flash point ( C.) 72 77 Source: KMITL Sci. Tech. J. Vol. 6 No. 1 January-June. 2006, p. 43

(13) TABLE-US-00003 TABLE 3 Typical Specification of FT-Jet Fuel Typical Product Specification FT-Jet Fuel Acidity mg KOH/g 0.10 Aromatics % vol max <25.0 Sulfur mass % <0.40 Distillation C. 50% recovered Min 125 C. max 190 C. End Point 270 C. Vapor Pressure kPa max 21 Flash Point C. Density 15 C., kg/m3 750-801 Freezing Point C. max 51 Net Heat Combustion MJ/kg min 42.8 Smoke Point mm, min 20 Naphthalenes vol % max <3.0 Copper Corrosion 2 hr @ 100 C., max No 1 rating Thermal Stability Filter Pressure drop mm Hg, max 25 Visual Tube rating, max <3 Static Test 4 hr @ 150 C. mg/100 ml, max Existent Gum mg/100 ml, max

(14) Naphtha can be generally defined as a distilled fraction of the Fischer-Tropsch FT hydrocarbon liquids, categorized by way of example with a typical boiling range of 30 C. to 200 C., and more preferred 30 C. to 105 C. The specific naphtha specification will be optimized for each application to maximize syndiesel production and partially or fully eliminate the naphtha byproduct.

(15) Suitable examples of FT reactors include fixed bed reactors and slurry-bubble reactors such as tubular reactors, and multiphase reactors with a stationary catalyst phase. For the slurry-bubble reactor, the FT catalyst particles are suspended in a liquid, e.g., molten hydrocarbon wax, by the motion of bubbles of syngas sparged into the bottom of the reactor. As gas bubbles rise through the reactor, the syngas is absorbed into the liquid and diffuses to the catalyst for conversion to hydrocarbons. Gaseous products and unconverted syngas enter the gas bubbles and are collected at the top of the reactor. Liquid products are recovered from the suspending liquid using different techniques such as separators, filtration, settling, hydrocyclones, and magnetic techniques. Cooling coils immersed in the slurry remove heat generated by the reaction. In a fixed bed reactor, the FT catalyst is held in a fixed bed contained in tubes or vessels within the reactor vessel. The syngas flowing through the reactor vessel contacts the FT catalyst contained in the fixed bed. The reaction heat is removed by passing a cooling medium around the tubes or vessels that contain the fixed bed. Other possibilities for the reactor will be appreciated by those skilled.

(16) In the FT process, H.sub.2 and CO combine via polymerization to form hydrocarbon compounds having varying numbers of carbon atoms. Typically 70% conversion of syngas to FT liquids takes place in a single pass of the FT unit. It is also common practice to arrange the FT reactors in series and parallel to achieve conversion levels of 90+%. After the FT separation stage to divert the unconverted syngas and light hydrocarbons, the FT liquids are directed to the hydrocarbon upgrader unit denoted as 27. The upgrader unit typically contains a hydrocracking step 24 and a fractionation step 26.

(17) Hydrocracking denoted as 24 used herein is referencing the splitting an organic molecule and adding hydrogen to the resulting molecular fragments to form multiple smaller hydrocarbons (e.g., C.sub.10H.sub.22+H.sub.2.fwdarw.C.sub.4H.sub.10 and skeletal isomers+C.sub.6H.sub.14). Since a hydrocracking catalyst may be active in hydroisomerization, skeletal isomerization can occur during the hydrocracking step. Accordingly, isomers of the smaller hydrocarbons may be formed. Hydrocracking a hydrocarbon stream derived from Fischer-Tropsch synthesis preferably takes place over a hydrocracking catalyst comprising a noble metal or at least one base metal, such as platinum, cobalt-molybdenum, cobalt-tungsten, nickel-molybdenum, or nickel-tungsten, at a temperature of from about 550 F. to about 750 F. (from about 288 C. to about 400 C.) and at a hydrogen partial pressure of about 500 psia to about 1,500 psia (about 3,400 kPa to about 10,400 kPa).

(18) The hydrocarbons recovered from the hydrocracker are further fractionated 26 and refined to contain materials that can be used as components of mixtures known in the art such as naphtha, diesel, kerosene, jet fuel, lube oil, and wax. The combined unit consisting of the hydrocracker 24 and hydrocarbon fractionator 26 are commonly known as the hydrocarbon upgrader 27. As is known by those skilled in the art, several hydrocarbon treatment methods can form part of the upgrader unit depending on the desired refined products. The hydrocarbon products are essentially free of sulfur. The diesel may be used to produce environmentally friendly, sulfur-free fuel and/or blending stock for diesel fuels by using as is or blending with higher sulfur fuels created from petroleum sources.

(19) Further, useable energy commonly generated as steam from the gasification stage, denoted by numeral 35, may be used to generate electric power 38. This is equally true of useable energy that can be drawn from the Fischer-Tropsch unit, owing to the fact that the reaction is very exothermic and this represents a useable source of energy. This is denoted by numeral 40.

(20) Turning now to FIG. 2, shown is a preliminary embodiment of the technology of the instant invention. As is evinced from FIG. 2, many of the preliminary steps are common with that which is shown in FIG. 1. Table 4 lists a series of biomass species with calorific values for the purposes of examples. Table 5 sets forth component analysis of examples of biomass.

(21) TABLE-US-00004 TABLE 4 Proximate analysis and calorific values of different biomass resources Calorific Ash Volatile Fixed Biomass value content matter Carbon Species (Kcal/Kg) (%) (%) (%) Bagass 3406-4403.6 1.8-22.1 18.2-86.3 7.0-70.8 Bamboo Dust 3632-4731 5.8-16.5 71.6-76.5 9.3-21.0 Coconut coir 4318 17.2 69.6 13.2 Coconut fibre 4332 4.7 82.1 13.2 waste Coconut shell 3649 1.9 79.9 18.2 Coir pith 4146 9.1 62.4 28.5 Corn cob 85.4 2.8 Corn stalks 8.1 6.8 Cotton gin waste 88.0 5.4 Cotton shell 4360 4.6 72.2 23.3 Groundnut shell 4200-4680 2.3-5.4 72.2-77.9 19.8-22.9 Mustard shell 4126-4320 3.7-9.4 72.5-79.7 13.9-18.1 Mustard stalk 4018-4473 2.6-17.2 60.9-80.0 14.3-21.9 Pine needles 4750 1.5 72.4 26.1 Rice Bran 3950 13.1 75.7 11.2 Rice Husk 3000-3618 13.9-22.4 62.1-68.9 12.7-41.2 Rice straw 3730 15.5 68.3 16.2 (ground) Sugarcane 4120-4390 4.8-10.9 70.4-77.4 14.9-19.2 leaves Sweet Sorghum 4124-4230 7.4-7.7 74.0-76.0 16.6-18.3 stalk Wheat stalk 3912 5.7 78.7 15.6 Wheat straw 4100-4516 6.4-8.0 69.6-80.6 11.7-24.0 Municipal solid 1345-3376 27.5-70.0 25.0-55.1 4.0-17.4 waste Forestry waste 4000-4500 0.25-3 2-5 66-69 Source: Biomass-Thermo-chemical Characterization, Ed. PVR Iyer, TR Rao & PD Grover, Biomass Conversion Laboratory, Chemical Engineering Department, IIT Delhi

(22) TABLE-US-00005 TABLE 5 Sample component analysis of biomass (wt % on dry basis) Biomass Hemi- Species Cellulose cellulose Lignin Extractives Ash Bagasse 33.6-41.3 22.6-27.0 15.0-18.3 13.7-18.4 2.9 Coconut coir 47.7 25.9 17.8 6.8 0.8 Coconut shell 36.3 25.1 28.7 8.3 0.7 Coir pith 28.6 15.3 31.2 15.8 7.1 Corn cob 40.3 28.7 16.6 15.4 2.8 Corn stalks 42.7 23.6 17.5 9.8 6.8 Cotton gin 77.8 16.0 0.0 1.1 5.4 waste Rice husk 31.3 24.3 14.3 8.4 23.5 Rice straw 30.2-41.36 24.5-22.7 11.9-13.6 5.6-13.1 16.1-19.8 Wheat straw 30.5-40.0 28.9 16.4 7.38-13.4 7.0-11.2 Source: Biomass-Thermo-chemical Characterization, Ed. PVR Iyer, TR Rao & PD Grover, Biomass Conversion Laboratory, Chemical Engineering Department, IIT Delhi

(23) Conveniently, the initial feedstock to the gasifier may be any one of coal, biomass, petroleum resids, municipal waste, plastics, wood, demetallized tire scrap, forestry waste, waste water byproduct, sewage biomass, livestock waste products, agricultural byproduct and waste, carbonaceous material and mixtures thereof.

(24) As is widely appreciated by those of skill, the hydrogen to carbon monoxide ratio of the clean syngas leaving the biomass gasifier stage once it has passed the cleanup stage 18, is generally 1:1. In the embodiment shown in FIG. 2, the carbon dioxide removal stage 20, at least a portion of the carbon dioxide 42 may be reintroduced into the gasifier 14 for purposes of controlling the reaction therein. Once the CO.sub.2 is removed, the procedure follows the unit operations as identified in FIG. 1.

(25) As the key difference, one of the most effective procedures in the instant technology, relates to the fact that once the product fractionation stage has been completed and the naphtha 28 formulated, it has been found that by inclusion of the hydrogen generator using naphtha as the primary source, significant results can be achieved in the production of the synthetic diesel. This is effected by transferring at least a portion of the naphtha fraction created to a hydrogen steam generator 44, shown in the example as a steam methane reformer (SMR). This results in the formation of the hydrogen rich stream 52. This procedure is well known and is perhaps one of the most common and economic methods for synthesizing hydrogen. The general reaction is as follows:
Natural Gas+Naphtha+Steam+Heat.fwdarw.CO+nH.sub.2+CO.sub.2

(26) The steam reformer may contain any suitable catalyst and be operated at any suitable conditions to promote the conversion of the naphtha hydrocarbon to hydrogen H.sub.2 and carbon monoxide. The addition of steam and natural gas may be optimized to suit the desired production of hydrogen and carbon monoxide. Generally natural gas or any other suitable fuel can be used to provide energy to the SMR reaction furnace. The catalyst employed for the steam reforming process may include one or more catalytically active components such as palladium, platinum, rhodium, iridium, osmium, ruthenium, nickel, chromium, cobalt, cerium, lanthanum, or mixtures thereof. The catalytically active component may be supported on a ceramic pellet or a refractory metal oxide. Other forms will be readily apparent to those skilled.

(27) As has been discussed herein previously, it is unusual and most certainly counter-intuitive to effectively destroy the naphtha in order to generate a hydrogen rich stream as the naphtha is commonly desired as primary feedstock for gasoline production. Although this is the case, it is particularly advantageous in the process as set forth in FIG. 2. The steam methane reformer may be augmented in terms of the hydrogen using natural gas 46, or using refinery gas 48 from the Fischer-Tropsch reactor 22 and the hydrocarbon upgrader 27. Energy recovered from the SMR 44 in the form of steam may be distributed via line 50 for production of electric power 38.

(28) Once the hydrogen rich stream 52 has been formulated in the SMR, the same is introduced into the syngas stream exiting syngas clean-up stage 18. At this point, a hydrogen rich stream from the SMR unit is combined at an optimal rate with a relatively lean hydrogen gas stream to generate the optimal Fischer-Tropsch syngas feed. This commingled or mixed stream is subject to the carbon dioxide removal and acts as a feedstock to the Fischer-Tropsch reactor 22. At the point of entering the Fischer-Tropsch reactor 22, the stream has a hydrogen to carbon monoxide ratio of approximately 1:1 to 5:1, preferably 2:1 as indicated by numeral 53. Optionally, a portion 54 of the hydrogen rich stream 52 may bypass the CO.sub.2 removal unit and feed the Fischer-Tropsch unit directly at 53. Once the carbon dioxide removal stage 20 has been effected, the hydrogen to carbon monoxide ratio is approximately 2 and is then subsequently introduced into the Fischer-Tropsch reactor 22 and subjected to the same steps that have been discussed with respect to FIG. 1. The results are quite substantial, providing the naphtha recirculation route and particularly using the naphtha as a feedstock to generate a hydrogen rich stream, the result is syndiesel production in great excess to that which is discussed in FIG. 1. As an example, the syndiesel production by following the methodology of FIG. 2 results in a 977 barrel per day (bbl/day) production based on a 20 tonnes per hour biomass feed.

(29) Subsequently, a small portion of the hydrogen rich stream 52 may be removed and treated on by a common hydrogen purification unit, a typical example is a Pressure Swing Adsorption unit (PSA) 55, to create a high quality hydrogen stream 56 for use in the hydrocarbon upgrader unit 27.

(30) FIG. 3 sets forth a further interesting variation on the overall process that is set forth in FIG. 2. In this variation, the process results in the formulation of not only diesel, but also jet fuel or aviation fuel. The operations common with FIG. 2 are denoted with similar numerals. In this process variation, a split product is made between the jet fuel and diesel fuel. As an example, the split may be 25%:75% between jet fuel and diesel production from the fractionator 26. In order to effect this, jet fuel as indicated by numeral 59 in FIG. 3, requires modification of the fractionation unit operation 26. As will be appreciated by those skilled in the art, the fractionation unit operation can be modified for the jet fuel recovery by adding a suitable side stripper as part of the fractionation unit operation 26. In terms of further modifications to the overall process set forth in FIG. 2, a hydrotreater step 57 should be considered for the hydrocarbon cracking unit. The hydrotreater is a method to ensure the stability of the refined products by addition and saturation of the product with hydrogen. The jet fuel produced is unique in that it will be of very high purity and free of sulfur compounds, thus coveted as a Clean Green aviation fuel.

(31) A further variation of the overall process embraced by the technology discussed herein is shown in FIG. 4. In essence, the process flow of unit operations shown in FIG. 4 is an amplification of the process as shown in FIG. 2 and essentially augments further utilization of carbon and hydrogen to provide an alternate stream for introduction into the Fischer-Tropsch reactor 22. This has dramatic consequences on the production of syndiesel. As with the previous figures, the similarly denoted unit operations are common in FIG. 4. From the flow diagram, it is evident that the SMR unit operation 44 FIG. 2 is absent in this flow diagram. This unit operation has been replaced with an ATR (Autothermal Reformer) unit operation, denoted by numeral 60. Both the naphtha and the refinery gas, 62 and 64, respectively, may be combined or separately transformed in the ATR unit 60. Utility heating for the ATR may be provided by natural gas 66. Oxygen may be introduced at 70. The ATR is useful to produce some hydrogen and carbon monoxide syngas which is, of course, useful to introduce into and further enhance the Fischer-Tropsch reactor 22. External hydrogen may be used for the hydrocarbon upgrader 27 requirement. The formed syngas from the ATR is denoted by line 68 and is introduced in advance of the carbon dioxide removal stage 20. Alternatively, a portion of 68 or the entire stream 68 may be introduced after the CO.sub.2 removal unit 20. Additional carbon dioxide 69 may also be provided to the ATR to optimize the augmented syngas composition to the Fischer-Tropsch unit 22.

(32) Turning to FIG. 5, what is shown is yet another variation of the overall process according to the present invention combining the benefits of FIGS. 2 and 4. In this embodiment, both the SMR and ATR unit operations are amalgamated into the generic circuit with one embodiment of the present invention to convert all the carbon introduced as biomass feed to high value syndiesel product. This has dramatic consequences in terms of productivity of the diesel as is clear from an output of, as an example, 2,027 barrels per day (bbl/day) based on 20 tonnes per hour of biomass feed. In this embodiment, the refinery gas 64 from the FT unit 22 and the upgrader unit 27 is employed as feedstock to the ATR unit 60. Further, naphtha is employed as feedstock to the SMR unit 44 to generate a hydrogen rich syngas. Further, the refinery gas 64, oxygen 70, natural gas 66 and carbon dioxide 69 are commingled in optimized proportions and processed through the ATR 60 and blended with the SMR 44 hydrogen rich syngas to achieve the optimum syngas for combining with stream 53 to the FT unit 22. This effectively results in a net increase in carbon monoxide as well as hydrogen for use in the Fischer-Tropsch reactor 22. As is evident from the flow diagram, the Fischer-Tropsch reactor is effectively fed with the hydrogen rich stream generated from the SMR as well as the supplemental syngas stream generated from the ATR. The SMR stream and ATR stream are commingled with the hydrogen lean syngas stream exiting cleanup unit operation 18 and subsequently introduced into the Fischer-Tropsch reactor 22. As noted above, this has a very significant effect on the output of the syndiesel and takes advantage of the effectiveness of the naphtha recycle for generating the hydrogen rich stream as well as the ATR which contributes hydrogen and carbon monoxide for mixture with the lean gas stream. The combination of all these syngas streams can effectively result in the full transformation of all the carbon entering the process as biomass being converted to highly valuable green syndiesel without by product hydrocarbons.

(33) Referring now to FIG. 6, shown is a further variation of the overall process which is similar to that which is shown in FIG. 5, with the exception of the absence of gasifier 14 and syngas cleanup operation 18.

(34) While the preferred embodiments of the invention have been shown and described, modifications thereof can be made by one skilled in the art without departing from the spirit and teachings of the invention. Reactor design criteria, hydrocarbon processing equipment, and the like for any given implementation of the invention will be readily ascertainable to one of skill in the art based upon the disclosure herein. The embodiments described herein are exemplary only, and are not intended to be limiting. Many variations and modifications of the invention disclosed herein are possible and are within the scope of the invention. Use of the term optionally with respect to any element of a claim is intended to mean that the subject element is required, or alternatively, is not required. Both alternatives are intended to be within the scope of the claim.

(35) Accordingly, the scope of protection is not limited by the description set out above, but is only limited by the claims which follow, that scope including all equivalents of the subject matter of the claims. Each and every claim is incorporated into the specification as an embodiment of the present invention. Thus the claims are a further description and are an addition to the preferred embodiments of the present invention. The discussion of a reference in the Background of the Invention is not an admission that it is prior art to the present invention, especially any reference that may have a publication date after the priority date of this application. The disclosures of all patents, patent applications and publications cited herein are hereby incorporated herein by reference, to the extent that they provide exemplary, procedural or other details supplementary to those set forth herein.