ADVANCED LOW ENERGY ENZYME-CATALYZED ... Library/Events/2013/Co2...1 Putting enzymes to work...
Transcript of ADVANCED LOW ENERGY ENZYME-CATALYZED ... Library/Events/2013/Co2...1 Putting enzymes to work...
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Putting enzymes to work™
ADVANCED LOW ENERGY ENZYME-CATALYZED SOLVENT FOR CO2 CAPTURE
John Reardon; Director, Engineering Project: DE-FE0004228 NETL National CO2 Capture Technology Meeting; Pittsburgh, PA July 9, 2013
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Company profile and project overview
Technical background & fundamentals
Progress and current status
Summary of results
Future work
OUTLINE
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• St. Louis-based biotechnology company
Developing lower cost, environmentally friendly solutions for CO2 capture for variety of applications
• Integrating proprietary biocatalyst delivery with various solvent systems
Company profile
AKERMIN INC.
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Project awardee, FFRDC, and Subcontract:
Enzyme Supply:
Test Site: (NCCC) Fabrication:
Project duration: 36 months (Oct 2010 to Sept 2013)
Funding
Participants, Duration, Funding
PROJECT OVERVIEW
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DOE Funding: $ 3,275,043 Akermin Cost share: $ 2,881,695 Total Project: $ 6,156,738
Instrumentation:
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Indicative temperatures and pressures “simple solvent system”
SCHEMATIC BASIC OPERATION
*Temperatures shown here are indicative of ~ adiabatic scenario using potassium carbonate regenerated at near ambient pressure.
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BIOCATALYST
*Vacuum blower: Leverage low quality steam to reduce equivalent work
VBLR
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Coated packing: Akermin’s first generation biocatalyst delivery system
CORE TECHNOLOGY FOR THIS PROJECT
Proprietary formulation achieves high activity and stability
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ENZYME
SOLUTION OF MONOMERS AND ADDITIVES
ENZYME SUSPENSION
COATING
ASSEMBLY
SEM IMAGE OF COATING
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CA accelerates hydration of CO2 to bicarbonate:
Base captures proton to complete reaction
Akermin explored numerous CAs
CA developed by Novozymes is top candidate Highly active
Resistant to major impurities in flue gas
Thermostable
Resistant to high pH (9-10.5)
High expression level, few impurities
CHEMISTRY: CA-CATALYZED CO2 ABSORPTION
Key point: CA mechanism is potentially applicable in many basic solvent systems
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kcat = 106/sec
Active site of CA
𝐻2𝑂 + 𝐶𝑂2 ⇌ 𝐻+ + 𝐻𝐶𝑂3−
CA
𝐵 + 𝐻+ ⇌ 𝐵𝐻+
CA: Carbonic Anhydrase
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Reducing column height enables certain solvent systems to become feasible
CATALYST REDUCES COLUMN PACKED HEIGHT
Goal: > 10X overall improvement in packing height
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BLANK (1X) 4X Improved 10X Improved 16X Improved Equilibrium
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The most effective and scalable method of CO2 capture from flue gas is via chemical reaction
BENEFITS OF TECHNOLOGY TO THE PROGRAM
Technology broadens the choice of solvents to be used in CO2 capture
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Both CCS cases include a $5.7 /MWh charge for CO2 Transport, Storage and Monitoring
Estimated Costs of Greenfield Super Critical PC Power Plant with CO2 Capture
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Achieve long-term stability
Minimize inhibition by flue gas impurities
Maximize enzyme retention, minimize leaching
Maximize activity (minimize diffusion resistance)
Replenishment of enzyme with minimal interruption
TECHNICAL CHALLENGES
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Installed at NCCC December 2012
BENCH UNIT CURRENTLY OPERATING AT NCCC
Sulzer M500X 8.33” ID x 26 ft packing Gas: 30 Nm3/hr Liquid: 275 LPH
Blank testing complete
Immobilized enzyme installed and has been operating since May 2013
Planning to operate through end of September 2013.
Instrumentation and controls:
Module Design and Fabrication:
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Data at design flow (31.5 Nm3/hr, 275 LPH, XCL ~ 25%)
BENCH UNIT DATA WITH BIOCATALYST
More than 1250 Hrs On Steam as of 7/09/2013, and continues.
Average CO2 inlet ~ 12% (dry basis)
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CO
2 C
aptu
re (
%)
Time On Stream (hours)
NETL-Akermin CO2 Capture System at NCCC
Parametric Testing Parametric Testing
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Biocatalyst achieved (average) 90.1% CO2 capture with ~20 Nm3/hr flue gas flow
compared to blank estimated ~2.8 Nm3/hr flue gas flow at 90% capture.
90% CO2 CAPTURE TEST (~20 SCMH)
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CO
2 C
aptu
re (
%)
Time On Stream (hr)
~7-fold higher gas flow achieves 90% capture with biocatalyst compared to without biocatalyst in the current column
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Component HSS
(mg/L)
Rate moles/L
/year
Loss of Solv. Capacity
(%/year)
Nitrite (NO22-) 25.1 0.0283 0.83%
Nitrate (NO3-) 6.41 0.0054 0.16%
Sulfate (SO42-) 36.1 0.0195 1.14%
Total 67.6 0.0532 1.55%
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PRELIMINARY (1 week of data), additional results pending
QUANTIFIED HEAT STABLE SALT ACCUMULATION
Preliminary estimate < 2%/year loss in capacity by HSS. Additional data and analytical results are pending.
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Component Sample #1 Sample #2
O2 ND ND
Ar+ O2 0.01% 0.01%
N2 0.01% 0.01%
Net CO2 99.98% 99.98%
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NCCC sampled CO2 product and analyzed purity with Gas Chromatography
QUANTIFIED CO2 PURITY: ~99.98%
High selectivity is clearly demonstrated with a high purity product
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Five Key Areas of Heat Loss Affecting Reboiler Duty (Temperatures displayed in °C)
HEAT LOSSES ON BENCH-SCALE PLANT
Combined effects of heat loss result in higher reboiler duties than could be achieved under adiabatic conditions (e.g., larger scale)
Heat loss on flue gas feed impacts Trich solution here
Long steam line with low flows impacts steam quality
Heat loss from reboiler line results in lower maximum approach temperature
Heat loss on riser reduces Trich feed to STR
Reboiler and Stripper Heat Losses ~0.6 kW
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This plot used for comparing Aspen prediction and regeneration energy data at test condition
VACUUM REGENERATION: ASPEN VS. DATA
Aspen model agrees within ~ 2.5% of measured values.
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5.0
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0.3 0.4 0.5 0.6 0.7 0.8 0.9 1.0 1.1
Spe
cifi
c R
eb
oile
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eat
Du
ty (
GJ/
t CO
2)
Reboiler Pressure (bara)
Aspen Energy Prediction
Pilot REB Duty
REB-1 Pres. ΔT Hot
Approach Lean Loading Rich Loading
bara °C mol/mol K2CO3 mol/mol K2CO3
1.030 20.6 0.291 0.645 0.860 20.4 0.319 0.645 0.631 17.4 0.324 0.650 0.470 14.3 0.349 0.673 0.308 11.1 0.386 0.697
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ENERGY & EQUIVALENT WORK VS. REBOILER TEMP.
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• ~3.5 GJ/tCO2 with K2CO3, basic flow sheet
• Equivalent work < 150 kWh/ t CO2 for Steam + VBLR to 1.6 bar
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Equ
iv.
Wo
rk (
kWh
/t C
O2)
Reboiler Temperature (°C)
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Re
bo
iler
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at D
uty
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J/t
CO
2)
Reboiler Temperature (°C)
0.25 XC (Lean)
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0.35
0.30 (no kinetic limitation)
Using lower grade steam reduces the loss of power-generating capacity for the plant!
0.25 XC (Lean)
0.30
0.35
0.30 (no kinetic limitation)
Equiv. Work (Steam + VBLR) Reboiler Heat Duty Lower temperature regeneration reduces parasitic load at plant
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Demonstrated that significant acceleration of CO2 capture is achieved with immobilized CA in the absorber
Demonstrated 90% capture using K2CO3 salt solution
Demonstrated > 1200 hours online with no detectible decline in performance
Negligible heat stable salts accumulation
>99.9% purity of CO2 product
Near zero aerosol formation
30% - 50% reduction in equivalent work of steam regeneration, including vacuum blower
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SUMMARY OF RESULTS
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Complete TEA with PNNL (this project)
Beyond this project:
Scale-up, automate, and optimize manufacture of immobilized enzyme
Develop and demonstrate second generation replaceable enzyme delivery system
Demonstrate alternative solvents to further reduce regeneration energy and to lower equivalent work
Explore alternative biocatalyst-enabled flow sheets
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Outside of this project
FUTURE WORK
Wrapping up current project with final TEA and report.
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ACKNOWLEDGMENTS
US DOE-NETL Andrew Jones, Project Manager
Novozymes Generous supply of carbonic anhydrases
National Carbon Capture Center Test site and on-site operations support
PNNL Charles Freeman, Mark Bearden, James Collette, Dale King
Battelle Bradley Chadwell, Marty Zilka
EPIC Systems Inc: Module design, fabrication, controls programming
Emerson: Instrumentation and controls
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DOE/NETL: This material is based upon work supported by the Department of Energy National Energy Technology Laboratory under Award Number DE-FE0004228. Disclaimer: This presentation was prepared as an account of work sponsored by an agency of the United States Government. Neither the United States Government nor any agency thereof, nor any of their employees, makes any warranty, express or implied, or assumes any legal liability or responsibility for the accuracy, completeness, or usefulness of any information, apparatus, product, or process disclosed, or represents that completeness, or usefulness of any information, apparatus, product, or process disclosed, or represents that its use would not infringe privately owned rights. Reference herein to any specific commercial product, process, or service by trade name, trademark, manufacturer, or otherwise does not necessarily constitute or imply its endorsement, recommendation, or favoring by the United States Government or any agency thereof. The views and opinions of authors expressed herein do not necessarily state or reflect those of the United States Government or any agency.
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