Carbon Management Research in UKy -CAER
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Transcript of Carbon Management Research in UKy -CAER
Carbon Management Research in UKy-CAER
Supported byCarbon Management Research Group
Kentucky EEC - DEDIARPA-E
US DOE International CollaborationUS Department of Energy
Rodney AndrewsCenter for Applied Energy Research
University of Kentucky
Carbon Management Research Group• Build on E-ON US investment in carbon
management project
• Develop more energy and cost effective carbon management technologies
• Address specific materials, controls and waste management solutions
• Allow early adoption of technologies by Kentucky’s electric utilities
• Current Founding Members: Five Utilities, EPRI and KY DEDI
Three Research Topics
• Short-medium Term Projects– Post-Combustion CO2 Capture
• 0.1MWth Pilot-scale study• 0.5~1MWth Slipstream field testing at
members’ sites– Technical-Economic Analysis
• Long-term Project– Chemical Looping Combustion/
Gasification for Solid Fuels
CAER Pilot-Plant Research•Completed commissioning using K2CO3 Solvent
– Only reaches 3%-10% capture
•100-hour Preliminary Study using K2CO3/Piperizane (PZ)– Could reach 90% capture– Precipitation of PZ
•Two-month MEA with 32 runs using ceramic packing– MEA degradation vs. stripping temperature– Mass transfer under utility flue gas conditions
•1.5-year study using Aqueous Ammonia– Ammonia slip vs. rich-solution pH etc– Mass transfer/energy vs. packing and operating parameters– Troubleshooting and problem solving
•On-going new solution study– Catalyzed solvent– Formulated solvent
• Kentucky Energy and Environment Cabinet• Carbon Management Research Industrial Members
(AEP, Duke, Easy Ky Power, LG&E and KU, and EPRI)• APRA-E (three years) for post-scrubbing solution
dewatering• DOE International Collaboration (five years) on catalyst
development and CDI dewatering• DOE (four years) on slipstream-scale study on solvent-
based post-combustion CO2 capture process
Current Funding Mechanism
The History of Coal Fired Power Plant
CO2 Emission vs. Net Plant Efficiency (coal)
Do We Have to Pay for Separation
• Targeted Process: – From a dilute state to over 90% purity
• dStotal = dSsystem + dSsurrounding ≥ 0– the entropy of an isolated system which is not in
equilibrium will tend to increase over time, approaching a maximum value at equilibrium;
– the entropy change dS of a system undergoing any infinitesimal reversible process is given by δq / T, where δq is the heat supplied to the system and T is the absolute temperature of the system.
The Minimum Work for Separation Only
•The first law
•The Second law
from 14% to 90%
175 kJ/kg CO2
(166 Btu/kg CO2)~4% of coal HHV
CO2 Management Approach
Post CO2 Capture Process
Abs RegFlue Gas(CO2 ~14%)
Clean gas (CO2<1%)
Rich Sorbent
Heat
Lean Sorbent
CO2 Stream(>90%)
Challenges– Low CO2 concentration in flue gas
• High direct compression cost• High transportation cost•
– CO2 Enrichment Process• High energy consumption (50-
80% increasing in COE) • Finding appropriate technologies
CO2 Scrubbing Process Options
PC Flue Gas
IGCC
What does CCS COE Incremental Include?
Direct• CAPX • OPEX relating to
CCS only
Indirect
• Steam Extraction
• Makeup Power
Others• T.S.M• D.F.O
Heat Integration
• Stripper• Compressor
Capital Investment: The Priorities
Source:Vattenfall
The requirement of solvent is fast kinetic
The requirement of solvent is to have higher net cyclic
capacity
Conflicts (Impact will be discussed later on)
ΔHabs
kJ/gmolRate Constant
M-1S-2
Pamine, 40C atm x 103
MEA 84 6000 0.1
NH3 27-60 799 200
K2CO3 27 50 0
Solvents Comparison
New Solvents Development
• VLE -- for determining the solvent capacity and heat of absorption;
• Wetted Wall Column – for determining the reaction rate, the catalytic effect
Mini-scrubber and Pilot-scale
• Mini-scrubber, scaleup from WWC, is used for solvent and catalyst development
• Pilot-plant for selected solvent and catalyst
Absorb40°C1 atm
Steam 3 atm
CO2150 Bar
Strip117°C2 atm
12% CO230% MEA (7 m)
Lean0.2
Rich0.5
MonoEthanolAmine Absorption/Stripping
C
1.2% CO2
The Need for CCS Heat Integration
Heat Rejected
to CW (400 Btu/lb
CO2)
Heat rejected
(100 Btu/lb CO2)
Heat needed (1300 Btu/lb CO2)
Heat Rejected
(400 Btu/lb CO2)
Heat Rejected
(600 Btu/lb CO2)
Can We Get fully Heat Integration?
StripperCondenser
Rich Solution
L/R EHX ΔT Has to reject by polish EHX
Combustion Air
FG Dew Point
FG Temp Profile
Yes, but little FW Heating
Temp-limited
Steam extraction
Some, ALL??
Else??
CAER's CCS Technology
Two-stage stripping
Integrated Cooling Tower
Advanced Solvent
What We Have Proposed for DOE Slipstream Project
1. 2.
3. Engineering design, build and install an advanced CO2 capture system into an existing PC power plant at a 0.7 MWe slipstream scale (~15 TPD CO2)
Three novel processes will be designed and integrated: 2-stage solvent striping, cooling tower desiccant, and Hitachi solvent
1. Two-stage Stripping: - Increase solvent working capacity by providing a secondary air-stripping column following
the conventional steam stripping column. - Air stripping stream sent to boiler as combustion air to increase flue gas PCO2
exiting boiler
2. Integrated Cooling Tower: - Use regenerated CO2 stream waste heat to dry liquid desiccant- Liquid desiccant is used to dry cooling tower air Improved power plant cooling tower and
steam turbine efficiency
3. Advanced Hitachi Solvent: - Primary amine analogous to MEA
Team Structure
What will We Do?The design, start-up/commissioning of a 2MWth test facility
(1400cfm);Two proprietary solvents are to be tested for parametric
investigation and long-term verification;New corrosion resistance coatings for material used in CCS
system (access ports needed in scrubber and stripper areas)
Solvent degradation (liquid product and gaseous emissions from CCS)
A series of transient tests to quantify the ability of the carbon capture system to follow load demand.
Preliminary 3-D View of Slipstream Unit
• 80 ft tall• 1000 ft2 footprint
(15’x65’, but could be
rearranged)• 5 to 6 modulus with
100,000lbs/modulus
• Plus control/lab trailer and others
Testing Site: LG&E and KU’s Brown Generating Station