eere's biomass powerpoint presentation template · 2006-10-30 · this powerpoint template for...
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![Page 1: EERE's Biomass PowerPoint Presentation Template · 2006-10-30 · This PowerPoint template for EERE's Biomass Program provides an introduction-style slide background and a follow-on](https://reader033.vdocuments.pub/reader033/viewer/2022050521/5fa4dd0b68aba930900a4367/html5/thumbnails/1.jpg)
열적변환의 플랫폼 경제 분석
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Economics of Thermal Conversion
Examining economics of syngas in an integrated process & biorefinery design
Examples of specific thermochemical products for which detailed designs exist:
• Biomass syngas to hydrogen (complete)
• Biomass syngas to mixed alcohols with separation of ethanol (on-going)
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Performing A Detailed Design
Discounted Cash Flow Economic Spreadsheet
Product Selling Price
Process Flow Diagrams
Literature InformationCommercial Technology
DOE SponsoredResearch Results
(gasification/ gas clean up & conditioning)
Rigorous Material & Energy Balance
ASPEN Plus Software
Capital & Project Cost Estimation
Capital Costs from Other Studies
ICARUS Software Cost Estimation
Operating Costs Fixed & Variable
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Intermediate Syngas Price –Targets & Barriers
$0.00
$1.00
$2.00
$3.00
$4.00
$5.00
$6.00
$7.00
$8.00
Today SOT - Currentdesign
Gas clean up &conditioning - Goal
design
Feed handling &drying
Gasification Process integration
Inte
rmed
iate
cle
an, r
efor
med
syn
gas
pric
e ($
/MM
Btu
)
Research in this area results in the largest syngas cost reduction
$4.75 $5.25 $7.25 $3.93 $4.05
Plant size = 2,000 BD tonne/day
• DOE program targets based on intermediate syngas price to track progress toward reducing technical barriers
Decrease in syngas price due to increased yields, decreased capital costs, & efficiency gains
(2025)
(2010)
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$0.00
$1.00
$2.00
$3.00
$4.00
$5.00
$6.00
$7.00
$8.00
Current Design Goal Design
Inte
rmed
iate
cle
an, r
efor
med
syn
gas
pric
e ($
/MM
Btu
)
Fractional Conversion at 875oC
Model N1D1
Time, Hours
0 1 2 3 4 5
Fra
ctional C
onvers
ion
0.0
0.2
0.4
0.6
0.8
1.0
Methane
Benzene
Naphthalene
EthaneTar & Toluene
Current
Goal
Results from NREL’s PDU tar reformer
Tie in With Research
• Goal case yield is increased & capital cost is less
Potential Impact of Reformer Efficiency on Syngas Price
Attaining research goals = reduction in syngas price
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Progression of Analysis
Progression of analysis toward integrated biochemical/thermochemical biorefinery design
Syngas ProductionBiomass Hydrogen
Mixedalcohols
Syngas ProductionBiomass
Biomass Sugar Production Ethanol
(integration)
Mixedalcohols
Syngas ProductionBiomass
• Using results of biomass to H2 detailed design to move forward for mixed alcohol detailed design
• Begin by building stand-alone mixed alcohol design
• Build off of stand-alone mixed alcohol analysis and stand-alone ethanol analysis to create a biochemical/thermochemical integrated biorefinery design
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Biomass Gasification – Syngas to Products
• FY 2003 NREL’s preliminary screening study showed H2 to be technically and economically feasible product from biomass gasification
• H2 was picked as a model product to show effect of process integration & economics of a final product from biomass gasification
• Performed detailed process design and modeling using Battelle Columbus Laboratory (BCL) low pressure, indirectly-heated gasifier
Gas composition mol% (dry) H2 23.85
CO2 12.79 CO 42.18 CH4 15.36 C2H2 0.41 C2H4 4.35 C2H6 0.29 C6H6 0.13
tar (C10H8) 0.23 NH3 0.32 H2S 0.07
H2:CO molar ratio 0.57 Gasifier efficiency 72.1% HHV basis
71.8% LHV basis
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Two designs examined based on catalytic tar destruction and heteroatom removal work at NREL:
• current design – defines today’s state of the technology
• goal design – shows the effect of overcoming R&D technical barrier
Compound Current GoalMethane (CH4) 20% 80%
Ethane (C2H6) 90% 99%
Ethylene (C2H4) 50% 90%
Tars (C10+) 95% 99.9%
Benzene (C6H6) 70% 99%
Ammonia (NH3) 70% 90%
Tar reformer conversion #’s
Syngas Clean Up & Gas Conditioning
Higher conversions for goal case; notably methane.
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Both designs broadly consist of:
• feed handling, drying, gasification, gas clean up and conditioning, shift conversion, and purification integrated with a steam and power generation cycle
Current Goal
Tar reformer Bubbling fluidized bed with 1% per day catalyst replacement
Reactor vessel & catalyst regeneration
vessel operating isothermally
Steam methane reformer (SMR)
SMR downstream of sulfur removal
None (SMR eliminated)
Main design differences:
Biomass Gasification - Detailed Design
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areas with significant heat recovery
• FT & mixed alcohols will have large amount of heat available in synthesis step due to exothermic reactions
Integration is Important
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Syngas Production is Large Contribution to Product Price
• This is true of other products, not just H2
• An estimation of the syngas cost can be made and used as a benchmark……………however, it doesn’t make sense to look at just stand-alone syngas production because integration is important and a key to economical process designs
Case 2 - Direct: GTI, HGCU, ATR, shift, conv MeOH, stm turbine
Case 1 - Indirect: BCL, scrubbing, stmreformer, shift, conv MeOH, stm turbine
Clean, reformed syngas generation = 60-64% of total capital in thermochmeical conversion
feed prepgasificationO2 plant (Case 2 only)clean up & cooling
syngas compression (Case 1 only)reformingCO2 removalMeOH synthesis & compressionpower generation
7%
14%
15%
9%15%
9%
22%
9%8%
6%
19%
9%
22%
5%
27%
4%
From FY 2003 preliminary screening study
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($/MMBtu, LHV)Current Goal
Intermediate syngas price 7.25 5.25
Stand-alone syngas price 8.67(20% higher)
7.10(35% higher)
Syngas Price – Integration Results & Lower Price
• More economical to build entire syngas generation to fuels production plant than to purchase syngas due to process integration advantages
• Completed analysis; NREL technical report available at www.nrel.gov/docs/fy05psti/37408.pdf
• Intermediate – Price of clean, reformed syngas in an integrated process.
• Stand-alone – Price of syngas with synthesis steps downstream of gas clean up & conditioning removed, natural gas used as fuel, and heat balance is reconfigured.
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-$2.00 -$1.50 -$1.00 -$0.50 $0.00 $0.50 $1.00 $1.50 $2.00 $2.50
Cooling Water and OtherUtilities
Steam System and PowerGeneration
Steam Methane Reforming &BOP
Compression
Tar Reforming, & Quench &sulfur removal
Gasification
Feed Handling and Drying
Feedstock
Capital Recovery Charge Raw Materials Process ElectricityElectricity Generated Fixed Costs
syngas = $7.25/MMBtu
$2.45 $0.81
$1.15
$0.54
$1.47
$0.69
$0.67 -$0.69
$0.17
(34%)(11%)
(16%)
(7%)
(20%)
(10%)
(0%) Net
(2%)
-$2.00 -$1.50 -$1.00 -$0.50 $0.00 $0.50 $1.00 $1.50 $2.00 $2.50
Cooling Water and Other Utilities
Steam System and Pow erGeneration
BOP
Compression
Tar Reforming, & Quench & sulfurremoval
Gasif ication
Feed Handling and Drying
Feedstock
Capital Recovery Charge Raw Materials Process ElectricityElectricity Generated Fixed Costs
syngas = $5.25/MMBtu
$2.18 (42%)$0.72 (14%)
$0.60 (11%)
$1.02 (19%)
$1.49 (28%)
$0.04 (1%)
$0.70 -$1.77
(-20%) Net
$0.27 (5%)
Reforming cost is reduced and shifted to a different plant section
($0.64 vs $1.23/MMBtu contribution to syngas price)
Intermediate Syngas Cost Contribution –Current & Goal Design
Current Design
Goal Design
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• Dec 2004 refocused thermochemical conversion to examine synergies & integration into a sugars biorefinery
• Mixed alcohols detailed design is a follow on to the biomass to H2study and validates initial December spreadsheet material balance & cost calculations
Mixed Alcohols Analysis
Ethanol via bioconversion
Corn Stover 2,000 dMT/day
Ethanol198,400 gpd
Lignin-rich Residue 600 dMT/day
Steam &Power
Gas-FiredCHP Plant
SyngasProduction Synthesis
Chemical Alcohols
11,800 gpd n-Propanol9,100 gpd n-Butanol
11,800 gpd Amyl/Hex Alcohols
Biomass Residues1,205 dMT/day
SyngasEthanol
98,000 gpd
Ethanol296,400 gpd
Any products from sugars will be made in both the sugars biorefinery and the Integrated Biorefinery.
Ethanol via bioconversion
Corn Stover 2,000 dMT/day
Ethanol198,400 gpd
Lignin-rich Residue 600 dMT/day
Steam &Power
Gas-FiredCHP Plant
SyngasProduction Synthesis
Chemical Alcohols
11,800 gpd n-Propanol9,100 gpd n-Butanol
11,800 gpd Amyl/Hex Alcohols
Biomass Residues1,205 dMT/day
SyngasEthanol
98,000 gpd
Ethanol296,400 gpd
Any products from sugars will be made in both the sugars biorefinery and the Integrated Biorefinery.
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Stand Alone Mixed Alcohols
Feed Handling andConditioning Gasification
PreliminarySeparation
DriedBiomass
Ethanol
Biomass CrudeSyngas
Mixed AlcoholSynthesis
SyngasCompression
Tar ReformingAnd Scrubbing
Crude
ProductsH
igh PSyngas
ScrubbedSyngas
C3 +Alcohols
Mixed
Alcohols
Methanol
H2, CO, CO2, CH4
• First step, stand alone system
• Conducted literature search - gathered information including types of catalysts, yields, operating conditions, and syngas requirements
• H2:CO ratio is crucial; desired value of about 1
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Stand Alone Mixed Alcohols
• Maximum hydrocarbon conversion in conjunction with optimal/most economical gas clean up and conditioning steps is challenging
• Selected modified FT catalyst (MoS2-variation) based on its ability to produce linear alcohols & higher sulfur tolerance
• Working on modifying biomass to H2 model for mixed alcohols production using BCL gasifier
• Milestone report due 7/18/05
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Feed PrepBiomass
Dryer
Gasification (BCL, & cyclones)
Scrubber Syngas Compression
Char & Sand
Char combustor & cyclonesAir
SteamFlue gas
Tar reformer
Sand
Ash
Water
Totreatment SteamSteam
Reformer
LO-CAT
Sulfur
Amine System
CO2
Gas Compression
Mixed Alcoholssynthesis
Liquids
Mol sieve Separation EtOH
C3+ alcohols
Gas
MeOH
Steam to reformer
Steam to gasifier
DeaeratorIP LP VP
Cooling water
Process integration heat exchange
• Preliminary block flow diagram
• 20% single pass CO conversion
• 80% alcohol selectivity
• Recycle MeOH to extinction
purge to fuel
Stand Alone Mixed Alcohols -Simulation
Separation
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Integrated Sugars/Thermochemical Biorefinery
LignocellulosicBiomass
Fermentation
Catalysis
Syngas Production
Sugar Production
Ethanol
Products:propanol, butanol
other alcohols
Lignin-rich Residues
Low QualityResidues
CHP Distillation
• Next step, in FY 2006 will combine mixed alcohols and ethanol stand alone systems to create an optimized biochemical/thermochemical biorefinery
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Acknowledgements
Additional analysts:
Andy Aden
Tim Eggeman
Matt Ringer
Bob Wallace
John Jechura
Kelly Ibsen