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Testing of Pre-Combustion CO2 Capture
Technologies at the National Carbon
Capture Center
John Wheeldon, Electric Power Research Institute
Tony Wu, Southern Company Services
2012 Gasification Technologies Conference
Washington, October 28 to 31, 2012
• 80% funded by US Department of Energy with 20% cost share
from major power and coal companies.
- High financial leverage for participants
DOE-Funded CO2 Capture Test Facilities in
Wilsonville, Alabama
Power Systems Development Facility (PSDF)
started combustion testing June 1996 and
gasification Sept. 1999.
In May 2009 PSDF transitioned to the
National Carbon Capture Center (NCCC).
Existing facilities used to support development
of pre-combustion CO2 capture.
Additional facility, the Post-Combustion
Carbon Capture Center (PC4) built and
started testing March 2011.
Located at adjacent power plant, Alabama
Power’s Plant Gaston near Birmingham.
Role of NCCC in CO2 Capture Technology Development
• Supports transition from laboratory to
commercial environment.
• All necessary infrastructure to support
testing of developer’s technology.
• Experienced operators and maintenance
staff.
• Comprehensive data collection and
analysis capability.
• Access to advanced analytical
techniques at SRI/UAB Birmingham.
• Flexible facilities allow for scale-up from
bench- to engineering-scale.
Provides first-class facilities to test developer’s technologies for extended periods under commercially representative conditions with coal-derived flue gas and syngas. Simultaneous testing at a range of sizes helps accelerate development of cost-effective carbon capture technologies.
Testing support to advance developer’s
technologies is top priority
Oxygen-Blown, Entrained-Flow IGCC from DOE’s
Advanced Technologies Portfolio
Selection of technologies for testing supported by screening process
Pre-Combustion CO2 Capture R&D at NCCC
Able to provide raw and sweet syngas up to 200 psia and 450°F for up to 1000
hours. Also able to augment syngas with hydrogen and CO2.
Membrane Technologies Tested
Preparing to test Eltron’s membrane system using 4.5 kg/hr (10 lb/hr)
of sweet syngas
A. Syngas inlet B. Permeate exit C. Residual exit
Spiral-wound design using polymer
materials
• Over 3000 hours testing. Various
membranes exposed to raw shifted and
unshifted syngas.
Membrane Technology & Research (MTR)
CO2 Membrane
One micron
Protective Coating Layer
Selective Layer (1,000 Å thick)
Gutter Layer
Support Membrane
One micron
• Two 10-cm OD x 115-cm long membranes (4-inches x 45-inches) can be
installed and tested using up to 23 kg/hr (50 lb/hr) of syngas at 40 C (100 F).
Scale-Up Support for MTR Syngas Membranes
Membrane stamp,
0.5 kg/hr (1 lb/hr) Pilot module, 230
kg/hr (500 lb/hr)
Lab-scale module, 4.5 kg/hr
(10 lb/hr)
Hydrogen membranes CO2 membranes
Small pilot
module, 23 kg/hr
(50 lb/hr)
Includes 20-cm OD (8-inch)
membrane modules
Scale Up of MTR’s Membrane Technology
• Two-stage polymeric CO2 separation membrane
processing 225 kg/hr (500 lb/hr) sweet syngas.
– First stage at 40 C and 14 bar (100 F and 200 psi)
– Permeate compressed to 30 bar (435 psi) before
passing to second membrane stage.
• 15 kg/hr (35 lb/hr) of +98% pure liquefied CO2
produced at 30 bar and -30 C ( 435 psi and -22 F).
MTR’s skids being installed
H2S removal vessels
• Test program will start in
December, achieving +500 hours
of operation.
• Second run planned for early in
2013.
Sources: WPI
• Worcester Polytechnic Institute (WPI) awarded $1.5
million by DOE to test palladium membranes.
• Hydrogen dissociates to atoms at palladium surface
and diffuse across the membrane.
• 2.5-cm (1-inch) OD by 25-cm (10-inch) long by
membrane tube housed in oven to maintain
temperature close to 450°C (840°F). Designs tested:
• Palladium-only
• Palladium with gold layer for sulfidation protection.
• 4.5 kg/hr (10 lb/hr) of sulfur-free syngas augmented
to 30 vol% hydrogen provided by NCCC.
• Stable H2 flux with +99.9% purity achieved.
Membrane housed within tube
and located in oven
WPI Palladium-Based Hydrogen Membrane
• WPI has submitted a proposal to DOE to
scale up the membrane module from 4.5 to
23 kg/hr (10 to 50 lb/hr) syngas using
multiple membrane tubes to achieve 85 %
hydrogen recovery.
Exposing Membrane Materials to Syngas
• On behalf of DOE, exposed multiple formulations of
hydrogen membrane materials to determine how they react
to “sour” syngas.
• Over 1000 hours exposure at 390°C and 16 bar (740°F and
230 psia).
• Post-run analysis by X-ray photoelectron spectroscopy,
X-ray diffraction, scanning electron microscopy, energy
dispersive microscopy, inductively-coupled plasma optical
emission spectrometry, inductively coupled plasma mass
spectrometry, and weight loss.
• Results indicate palladium can resist sulfidation when
amalgamated with appropriate elements in correct
proportions.
• Testing accelerated understanding and opened up new
opportunities.
Ready to test other developer’s materials in similar manner
Media Processing Technology (MPT)
Membrane Development & Scale-Up
• Carbon molecular sieve (CMS) membrane deposited on
alumina tubes 5.7 mm OD x 76 cm long (30 inches long)
• Operates 250 to 300 C (480 to 570 F), tolerant to sulfur so can
use raw syngas augmented to 40% hydrogen
• Full-scale bundle (84 tubes) processes 23 kg/hr (50 lb/hr)
syngas: permeate 90+% hydrogen with yields around 30%.
• Added single-tube palladium membrane to purify CMS
permeate to achieve 99+% purity
– CMS permeate has some H2S so sulfur guard bed required.
TDA High-Temperature CO2 Sorbent
• Carbon sorbent that removes CO2 via strong physical adsorption
– CO2-surface interaction is strong enough to allow operation at elevated temperatures
– No covalent bond so regeneration energy low.
• Heat of adsorption of CO2 4.9 kcal/mole at 250 C and 20 bar (480 F and 290 psia)
– Selexol ~4 kcal/mol but at 20 C at 5 bar (70 F and 70 psia)
– Ability to regenerate at higher temperature and releasing CO2 at higher pressure
improves cycle efficiency up to 4%
• Completed over 200 cycles with sweet syngas at NCCC achieving 98+% CO2 removal from syngas at temperatures above 200 C (390 F)
• Preparing to test sorbents with WGS functionality
that allow simultaneous shift reaction and CO2
adsorption
– Allows for higher CO2 production for same
steam-to-CO ratio.
– Potential to improve cycle efficiency up to 6%.
Expansion of SCU Testing Capability
• Covered area includes solvent, high-
temperature mercury sorbent, and
water gas shift catalyst test units.
• New area will supply 225 kg/hr (500 lb/hr) syngas
to MTR’s CO2 separation membrane (late 2012)
and 360 kg/hr (800 lb/hr) to developer in
negotiation (mid 2013).
• Ohio State’s 360 kg/hr (800 lb/hr) Chemical
Looping Module to be located to left of photograph
(mid 2013).
• Contract discussions in progress with other
technology suppliers and further test campaigns
are expected.
Space and enthusiasm to support
other developers
Closing Comments
• The NCCC is able to test multiple pre-combustion technologies
simultaneously over a range of syngas flow rates
– This flexibility accelerates technology development.
• Testing developer’s technologies is NCCC’s top priority
– Support provided at design stage and during operation (with
operators and mechanical, electrical, and I&C services) to ensure
reliable accurate data are collected, efficiently and safely, and allow
the next stage of development to be planned successfully.
• Testing capabilities are being expanded to accommodate more
developers and test additional technologies at larger scales.
• Similar program in progress testing post-combustion capture
technologies.
Abbreviations Used
CMS carbon molecular sieve
DOE US Department of Energy
I&C instrumentation and control
MPT Media Process Technology
MTR Membrane Technology Research
NCCC National Carbon Capture Center
NETL National Energy Technology Laboratory
OD outer diameter
OSU Ohio State University
PC4 Post-Combustion Carbon Capture Center
PSDF Power Systems Development Facility
SRI Southern Research Institute
UAB University of Alabama, Birmingham
WGCU warm gas cleanup
WGS water gas shift
WPI Worcester Polytechnic Institute