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["Table 2.  Key Performance Parameters for Proposed Commercial Facility: Thermochemical- Pyrolysis Production of Biofuels"]
[]
["Project Title:","NREL Nov. 2010 Fast Pyrolysis to Transportation Fuels design case (NREL/TP-6A20-46586), H2 purchased Scenario"]
[{"$nulls":5},"[Metrics projected to commercial scale, based on demonstrated data]"]
["TECHNICAL DATA INPUTS"]
[]
["Section","Key Performance Parameter","Demonstrated Value(s)*","Target Value(s)\n(if different than demonstrated)","Basis/Justification**\n(consistent with Table 1)","Notes / Directions / Examples"]
["Product (s) and By-Products","List all products (biofuels and biofuel intermediates) and by-products serving as revenue.","naphtha and diesel blendstock, fuel gas",null,null,"Please list here.  Example Products: butanol, lipids, renewable diesel, jet fuel                                                              \nExample By-Products: electricity"]
["Feedstock (as delivered)","Feedstock Type(s)","Corn Stover","-",null,"Examples: corn stover, switchgrass, forest residues"]
[null,"Feedstock Cost ($/BDMT)","-",83,"based on USDA data, including delivery costs"]
[null,"Feedstock Moisture (wt %)",0.25,"-","USDA data, Mullen et al, 2010"]
[null,"C, H, N, O, S (wt %) (dry basis)","47.28, 5.06, 0.8, 40.63, 0.22%","-","Adapted from USDA data, Mullen et al, 2010"]
[null,"Ash content wt (%) (dry basis)",0.06,"-","USDA data, Mullen et al, 2010"]
["Pyrolysis","Gas Yield (kg/BDMT)","-",129,"based on USDA data for corn stover pyrolysis in pilot bubbling fluidized bed of quartz sand (Mullen et al, 2010)"]
[null,"Char/Ash Yield (kg/BDMT)","-","164"]
[null,"Water-Phase Yield (kg/BDMT)","-","108"]
[null,"Bio-Oil Yield (kg/BDMT) ","-",599.00000000000011]
[null,"Bio-Oil Moisture Content (wt%)","-","not available"]
[null,"Bio-Oil Oxygen Content (wt%)  (dry basis)","-",0.37940000000000002]
[null,"Energy Efficiency  across Pyrolysis (%)  (LHV) ","-","not available"]
["Bio-Oil Stabilization","Catalyst(s) usage/replacement in stabilization ($/gal biofuel(s))","-","not available",null,"if applicable"]
["    (if applicable)","H2 Consumption in Stabilization (kg/gal biofuel(s))","N/A","-",null,"if applicable"]
[null,"Stabilized Bio-Oil Yield (kg/kg of Bio-oil feed)","-","not available"]
[null,"Char and Ash Reduction in Stabilization (wt%)","-","not available"]
[null,"Metals Reduction in Stabilization (wt%)","-",0.98,"assumed guard bed performance for reduction of metals to 10 ppm levels to protect hydrotreating cats"]
[null,"Stabilized Bio-Oil Moisture Content (wt%)","-","[same as above]"]
[null,"Stabilized Bio-Oil Oxygen Content (wt%) (dry basis)","-","[same as above]"]
["Upgrading to Fuel(s)/","Catalyst(s) usage/replacement in upgrading ($/gal biofuel(s))","-","$1.8MM/yr catalyst replacement costs","based on typical catalyst replacement costs for petrochemical hydrotreating and hydrocracking unit operations","if applicable"]
["Product(s) (If applicable)","H2 Consumption in Upgrading (kg/gal biofuel(s))","-","0.03-0.045","Adapted from wood pyrolysis/upgrading lab data presented publically by UOP (Holmgren, J.; Nair, P.; Elliot, D.; Bain, R.; Marinangeli, R. “Converting Pyrolysis Oils to Renewable Transport Fuels: Processing Challenges & Opportunities.” National Petrochemical & Refiners Association Annual Meeting, San Diego, CA, 2008; March 9-11, 2008)","if applicable"]
[null,"Gas Yield in Upgrading (kg/gal biofuel(s) produced)","-","0.6 (including water)"]
[null,"Liquid Fuel(s)/Product(s) Yield in Upgrading (kg/kg oil feed)","-",0.42]
[null,"Liquid Fuel(s)/Product(s) Oxygen Content (wt%)  (dry basis)","-",1.5176E-2,null,"list separately for each product stream"]
[null,"Liquid Fuel(s)/Product(s) Moisture Content (wt%)","-","not available",null,"list separately for each product stream"]
[null,"Refinery Insertion Point for Liquid Fuel(s)","-","intermediate refinery insertion point (middle distillates stream)",null,"if applicable, list separately for each product/steam"]
[null,"Liquid Fuel(s)/Product(s) Miscibility with Petroleum Steam(s)","-","naphtha/diesel stream miscible",null,"list separately for each product stream"]
["Overall Yields","Overall Yield from Biomass (unit/BDMT)                                                               \n--Jet Fuel (gal/BDMT)\n--Diesel Fuel (gal/BDMT)\n--Naphtha/gasoline (gal/BDMT)                                                                          \n--Export Power (kWhr/BDMT)                                                              \n--Export Steam (MMBTU/BDMT)\n--Other products/byproducts (unit/BDMT)","-","47.8 gal/BDMT naphtha\n40.8 gal/BDMT diesel\n1.8 MMBTU/BDMT fuel gas","simulation based on above assumptions","Provide separately for each product and by-product (e.g. gal ethanol/BDMT), kW of excess electricity/BDMT)"]
[null,"Overall Gate-to-Gate Energy efficiency (%) (LHV)","-",0.7,"simulation based on assumptions","(Product(s) and by-products out)/(Biomass plus other input fuels in)"]
["Overall Usage Rates (based on demonstrated data and projected to commercial scale)","Chemicals and Materials Costs ($/gal biofuel(s))","-","<$0.28/gal N+D","H2 consumption and catalyst costs only; other chemical/material costs not available; based on simulations and above assumptions","Include enzymes, chemical, catalysts, import H2, other materials, solvents, etc"]
[null,"Utilities Imported to/Purchased for Process:\n--Electricity (kWhr/gal biofuel(s))                                                                  \n--Natural gas (MMBTU/gal biofuel(s))                                                                \n--Steam (MMBTU/gal biofuel(s)) ","-","138 kWhr/BDMT power","simulation based on above assumptions","Example: purchased electricity = 1.2kWh/BDMT"]
[null,"Purchased water (gal/gal biofuel(s))","-","not available",null,"Include process water, cooling water, boiler feed water makeup, etc."]
["Wastes (based on demo'd data/projected to commercial)","Waste Water for Treatment (gal/gal biofuel(s))","-","not available",null,"Include assumptions for water recycle/re-use"]
[null,"Solids Waste (kg/gal biofuel(s))","-",1.5,"simulation based on assumptions"]
["Capital Costs***  (projected to","Commercial Plant Design Capacity (BDMT/day)","-",2000,null,"Design capacity for capital cost estimate"]
["    commercial scale)","Total Capital Investment ($)","-","$200MM","assumed nth plant, Installed capital estimated using ICARUS, based on Aspen simulation; Indirect costs & contingency estimated using factors; Lang Factor of 5.5"]
["Labor Costs (projected to commercial scale)","Expected Commercial Plant Staffing (FTE)","-","not available",null,"Provide an estimate of the number of people it will take to operate the full-scale commercial plant. Include process operators and immediate supervision. Express as the number of Full Time Equivalent people."]
["* Provide the best value achieved to date based on actual data, not design specs or plans"]
["**Describe  the basis or justification for current best result and the scale at which it was achieved. Examples of basis include: number of hours at steady state (steady state typically defined as continuous operation of the integrated process for ≥3 residence times), or the results of a number of replicate short runs of the isolated process step, etc. Include how the measurement was made (e.g. analysis of the gasifier outlet stream using gas chromatography).  Reference information in Table 1 as necessary."]
["***For Capital estimates, please include the level of confidence in the data and provide ranges if applicable."]

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["Process Description [as taken from NREL design report]"]
["Biomass with 25% moisture content is dried to 7% moisture and ground to 3-mm-diameter size prior to being fed into a fluid bed pyrolyzer operating at 480°C and atmospheric pressure.  Standard cyclones remove solids consisting mostly of char particles entrained in the vapors exiting the pyrolyzer.  Vapors are condensed in indirect contact heat exchangers, yielding liquid bio-oil that can be safely stored at ambient conditions prior to upgrading to transportation fuels.  Non-condensable gases are recycled to the pyrolysis reactor after being combusted to provide process heat. This analysis assumes that pyrolysis solid products are sent to a combustor to provide heat for the drying and pyrolysis process. Excess solids consisting of char are sold as a low-heating-value coal substitute.  Because of concerns over the scalability of existing reactor designs, this study assumes that multiple 500 MT/day reactors are employed in parallel.  Bio-oil compounds are selected based on available Aspen Plus software compounds and may not share the same properties as compounds selected by NREL.  Bio-oil and char are collected in the storage section, which can store up to 4 weeks of product."]
["For hydrotreating and hydrocracking, this study modifies that reported publically by UOP for pyrolysis oil hydrotreating and hydrocracking (Marker, T. L. Opportunities for Biorenewables in Oil Refineries. Final Technical Report. United States DOEGO15085. Des Plaines, IL: UOP, 2005; Holmgren, J.; Nair, P.; Elliot, D.; Bain, R.; Marinangeli, R. “Converting Pyrolysis Oils to Renewable Transport Fuels: Processing Challenges & Opportunities.” National Petrochemical & Refiners Association Annual Meeting, San Diego, CA, 2008; pp. 9-11) by assuming that a smaller fraction of oil is separated for reforming purposes [none in the H2 purchased scenario].  Bio-oil’s aqueous phase can account for up to 70% of the bio-oil weight, which leaves only 30% for upgrading. This study assumes that the process can be optimized to only separate as much bio-oil as required to produce the needed hydrogen [none in the H2 purchased scenario]."]