Upload
others
View
1
Download
0
Embed Size (px)
Citation preview
© 2010 Electric Power Research Institute, Inc. All rights reserved.
Integration of Ion Transport Membrane Technology with Oxy-Combustion Power Generation Systems
Merrill Quintrell – Electric Power Research Institute ([email protected]) E P Ted Foster – Air Products and Chemicals Inc. ([email protected]) 2nd International Oxyfuel Combustion Conference 12th–16th September 2011
2
© 2011 Electric Power Research Institute, Inc. All rights reserved.
What Is Ion Transport Membrane (ITM) Oxygen?
ITM Oxygen
Unit
High Temperature /
High Pressure Air
99.5% O2
N2 / O2
Design options for ITM Oxygen process: – Power co-production – Minimum fuel consumption – Minimum CO2 emissions
Images courtesy Air Products. © Air Products. All rights reserved.
A proprietary ceramic membrane to separate oxygen from air
ITM Oxygen can be used for both IGCC and oxy-combustion power cycles
CO2 / H2O
3
© 2011 Electric Power Research Institute, Inc. All rights reserved.
• Single-stage high purity oxygen • All layers composed of the same ceramic material • Extremely selective and very fast electrochemical
transport for oxygen • Very compact
0.45 tonne/day (0.5 ton/day)
module
Porous membrane support
Dense, slotted backbone
Dense membrane
Hot Compressed Air
High Purity Oxygen Product
Oxygen flowing from air through dense membrane
One Membrane in Module
Spacer
Images courtesy Air Products. © Air Products. All rights reserved.
800-900oC (1500-1650oF) 14+ bara (200+ psia)
ITM Oxygen Membranes
4
© 2011 Electric Power Research Institute, Inc. All rights reserved.
0.45 tonne/day (0.5 ton/day)
Stack Progression to Commercial-Size Wafers
Images courtesy Air Products. © Air Products. All rights reserved.
ITM Oxygen – Wafers and Module Scale-up 0.9 tonne/day
(1 ton/day) Stack
5
© 2011 Electric Power Research Institute, Inc. All rights reserved.
ITM Oxygen Development Background
• Air Products (AP) has been developing ITM since 1988 and the Department of Energy (DOE) has been a principal funder of the technology since 1998
• AP/DOE development program is currently in Phase 3, with goal to design, build, and test an ITM Intermediate-Scale Test Unit (ISTU)
– 90 tonnes/day (100 tons/day) integrated with 5-MWe turbomachinery system
– U.S. DOE NETL, AP, EPRI, and others are involved
• DOE awarded additional US$65 million for expanding Phase 3 and US$71.7 million for Phase 5 to install a ceramic fabrication plant and to prepare for a 1800 tonnes/day (2000 tons/day) pre-commercial scale facility
• EPRI initiated a power industry-led collaborative to support the program in 2009. Project funders received:
– Background on ITM: its ceramics, development, and production
– Detailed performance modeling and economic assessment of ITM applied to both IGCC and oxy-combustion
– Integration schemes for ITM into IGCC and oxy-combustion
– Quarterly web-casts and annual site visits (ceramics facility, AP HQ, pilot site)
– Current EPRI project ends September 2011 with a plan to extend it
6
© 2011 Electric Power Research Institute, Inc. All rights reserved.
ITM with Oxy-Combustion Study Scope of Work
• Provide an overview of first ideas on integrating ITM into oxy-combustion systems, and the strengths and weaknesses of each
• Performance modeling with cryogenic ASU for comparison
– No CO2 purification
– CO2 purification with 75% and 90% CO2 capture
• Performance modeling for three ITM cases (with CO2 purification)
– ITM O2: 1-Stage, Direct-Fired, O2 supply at 38oC (100oF)
– ITM O2: 2-Stage, Direct-Fired, O2 supply at 538oC (1000oF)
– ITM O2: 2-Stage, Oxy-Fired, O2 supply at 538oC (1000oF); ITM unit exhaust sent to the CO2 purification unit
7
© 2011 Electric Power Research Institute, Inc. All rights reserved.
Potential Ways to Integrate ITM with Oxy
Case Integration Benefits Concerns Comment
1 ITM standalone using direct-fired natural gas (NG) combustor for heat
Power production, simplicity
CO2 produced is vented; cost of using NG; availability of NG
Simple concept but use of NG and CO2 production (although less than combined cycles) may limit use
2 ITM standalone using oxy-fueled fired heater
Power production; lower CO2 emissions, coal may be used rather than NG
Complexity and capital cost compared to Case 1; cost / availability of NG if used; developing fired heater
May be the best of the options unless capital cost is a principal concern
3 ITM integrated into boiler for heat
Lower CO2 emissions; potentially higher efficiency; may have a lower operating cost due to less use of NG
Concerns include: high-temperature material requirements; impacts on boiler operation and startup; pressure drop
Need to address technical unknowns before this would be viable
8
© 2011 Electric Power Research Institute, Inc. All rights reserved.
Feed Air Non-permeate, contains CO2
Oxygen Product, 38oC (100oF)
Expander Compressor
Heat Exchange
ITM Oxygen Unit
Non- permeate
Fuel
Oxygen Blower
Oxygen Cooling
ITM Options a. 1-stage, direct-fired cycle,
O2 supply at 38oC (100oF)
ITM Configurations in Study: Case a
Low Level Heat Recovery (optional)
9
© 2011 Electric Power Research Institute, Inc. All rights reserved.
Feed Air Non-permeate, contains CO2
Oxygen Product, 538oC (1000oF)
Expander Compressor
Heat Exchange
ITM Oxygen Unit (A)
Non- permeate
Fuel ITM Oxygen Unit (B) Oxygen
Cooling
Oxygen Blower
Low Level Heat Recovery (optional)
ITM Configurations in Study: Case b
ITM Options b. 2-stage, direct-fired cycle,
O2 supply at 538oC (1000oF)
10
© 2011 Electric Power Research Institute, Inc. All rights reserved.
Feed Air
ITM Oxygen Unit (B) Oxygen
Cooling
Non-permeate
Oxygen Blower
Expander Compressor
Heat Exchange (optional)
ITM Oxygen Unit (A)
Non- permeate
Fuel
Heat Exchange
Oxy-fired Combustion
Flue Gases To CO2
Recovery
Oxygen
ITM Configurations in Study: Case c
ITM Options c. 2-stage, oxy-fired cycle, O2
supply at 538oC (1000oF)
Oxygen Product, 538oC (1000oF)
Low Level Heat Recovery (optional)
11
© 2011 Electric Power Research Institute, Inc. All rights reserved.
Summary of Oxy-Combustion Modeling Results
• ITM Oxygen can contribute significantly to the overall power production of an oxy-combustion facility
• ITM Oxygen affords increased power cycle efficiency over cryogenic oxygen production
• At base-case fuel costs:
– Direct-fired ITM Oxygen cycles achieve 75% CO2 capture at 17% cost of electricity (COE) advantage over cryogenic oxygen cycles
– Oxy-fired ITM Oxygen cycles achieve 90% CO2 capture at equivalent COE to cryogenic oxygen-based cycles, but with 14% reduction in specific plant capital cost
• Lower natural gas costs increase the advantage of ITM Oxygen over cryogenic systems
Preliminary results with potential improvements in integration to come
12
© 2011 Electric Power Research Institute, Inc. All rights reserved.
• ITM Oxygen and Cryogenic ASU cycle cases:
1. Nominal 90% CO2 capture; 1%-point efficiency increase
2. Nominal 75% CO2 capture; 6%-point efficiency increase
NGCC/CCS
25%
30%
35%
40%
45%
50%
55%
0 500 (227) 1000 (455) 1500 (682) 2000 (909)
NGCC Conventional PC
Eff
icie
ncy
, HH
V
CO2 emissions, lb CO2/MWh (net) (kg CO2/MWh (net))
ITM
Cryogenic ASU
(2)
(1)
(1) (2) Oxy-Cryo ASU
Results Show Flexibility of ITM Process Options
13
© 2011 Electric Power Research Institute, Inc. All rights reserved.
Conclusions
• ITM Oxygen is a promising technology for lower-cost oxygen production
• ITM Oxygen has potential for economic benefits for oxy-combustion power generation
• ITM Oxygen will be significantly scaled up in the next few years in the 90 tonnes/day (100 tons/day) oxygen ISTU pilot plant
• Following the ISTU, the next step is a 1800 tonnes/day (2000 tons/day) facility in the late 2015 timeframe
• A ceramic fabrication facility to produce modules for a commercial-scale ITM Oxygen facility will be operating in 2013
14
© 2011 Electric Power Research Institute, Inc. All rights reserved.
Acknowledgment and Disclaimer
Neither Air Products and Chemicals, Inc. nor any of its contractors or subcontractors nor the United States Department of Energy, nor any person acting on behalf of either:
1. Makes any warranty or representation, express or implied, with respect to the accuracy, completeness, or usefulness of the information contained in this report, or that the use of any information, apparatus, method, or process disclosed in this report may not infringe privately owned rights; or
2. Assumes any liabilities with respect to the use of, or for damages resulting from the use of, any information, apparatus, method, or process disclosed in this report.
Reference herein to any specific commercial products, 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 Department of Energy. The views and opinions of authors expressed herein do not necessarily state or reflect those of the United States Department of Energy.
Acknowledgment
This technology development has been supported in part by the U.S. Department of Energy under Contract No. DE-FC26-98FT40343. The U.S. Government reserves for itself and others acting on its behalf a royalty-free, nonexclusive, irrevocable, worldwide license for Governmental purposes to publish, distribute, translate, duplicate, exhibit and perform this copyrighted paper.
Disclaimer
15
© 2011 Electric Power Research Institute, Inc. All rights reserved.
Together…Shaping the Future of Electricity