Sequestration Technology Manager

1. Sean Plasynski – National Energy Technology Laboratory Sequestration Technology Manager

2. Carbon Sequestration R&D Overview Global Task Force on Carbon Capture and Sequestration The Earth Institute – Columbia University Feb. 14, 2008 Sean Plasynski, PhD Sequestration Technology Manager National Energy Technology Laboratory Office of Fossil Energy

3. Annual CO2 Emissions Extremely Large • 1 million metric tons of CO2: • Every year would fill a volume of 32 million cubic feet • Close to the volume of the Empire State Building Data sources: Mercury - EPA National Emissions Inventory (1999 data); SO2 - EPA air trends (2002 data); MSW - EPA OSWER fact sheet (2001 data); CO2 - EIA AEO 2004 (2002 data)

4. Technological Carbon Management Options Improve Efficiency Sequester Carbon Reduce Carbon Intensity • Renewables • Nuclear • Fuel Switching • Demand Side • Supply Side • Capture & Store • Enhance Natural Sinks • All options needed to: • Affordably meet energy demand • Address environmental objectives

5. Core R&D Infrastructure Carbon Sequestration Leadership Forum Monitoring, Mitigation, & Verification Capture of CO2 Regional Carbon Sequestration Partnerships • Storage • Direct CO2 storage • Enhanced natural sinks Non-CO2 GHG Mitigation IntegrationProjects Break- through Concepts Initiated FY 2003 DOE’s Sequestration Program Structure

6. Carbon Sequestration Program Goals • Deliver technologies & best practices that validate: • 90% CO2 capture • 99% storage permanence • < 10% increase in COE (pre-combustion capture) • < 20% increase in COE (post- and oxy-combustion) • +/- 30% storage capacity

7. Key Challenges to CCS • Sufficient Storage Capacity ? • Cost of CCS ? • Permanence ? • Infrastructure ? • Transport Lines • Permitting • Regulatory framework • Public Acceptance (NIMBY  NUMBY) • Liability • Best Practices • Human Capital Resources

8. Sufficient Storage Capacity ? • Validate Storage Capacity to +/- 30% Accuracy

9. National Atlas HighlightsAdequate Storage Projected U.S. Emissions ~ 6 GT CO2/yr all sources Saline Formations North American CO2 Storage Potential (Giga Tons) Oil and Gas Fields Unmineable Coal Seams Hundreds of Years of Storage Potential Conservative Resource Assessment Available for download at http://www.netl.doe.gov/publications/carbon_seq/refshelf.html

10. Worldwide Geologic Storage Capacity(Thousands of Years of Potential Storage Capacity) 200,000 Maximum Capacity Potential Capacity (Gigaton CO2) 24 Gigatons CO2 Deep Saline Formations Annual World Emissions Depleted Oil & Gas Fields Coal Seams Storage Option Storage Options: IEA Technical Review (TR4), March 23, 2004 World Emissions: DOE/EIA, International Energy Outlook 2003, Table A10

11. Cost of CCS ? • < 10% increase in COE (pre-combustion capture) • < 20% increase in COE (post- and oxy-combustion)

12. CCS Is Expensive ! • 5–30% parasitic energy loss • 35–110% increase in capital cost • 30–80% increase in cost of electricity 2012 Program Goals Source: Cost and Performance Baseline for Fossil Energy Power Plants study, Volume 1: Bituminous Coal and Natural Gas to Electricity.

13. Post-combustion Pre-combustion Oxycombustion CO2 Compression Chemical looping OTM boiler Biological processes Ionic liquids MOFs Enzymatic membranes CAR process PBI membranes Solid sorbents Membrane systems ITMs Advanced physical solvents Advanced amine solvents Amine solvents Physical solvents Cryogenic oxygen Technology Advances Are Starting to Emerge Cost Reduction Benefit CO2 Compression Present 5+ years 10+ years 15+ years 20+ years Time to Commercialization

14. Permanence ? • Develop tools, protocols & best practices • Verify 99% storage retention

15. Tools, Protocols, and Best Practices All Risks & Leakage Pathways Are Being Studied • Environmental Risks • Migration into other strata, displacement of underground fluids, … • Health and Safety Risks • CO2 is a nontoxic, inert gas that displaces oxygen - asphyxiation • Economic Risks • Liability and operational considerations, EOR commercially proven Best Practices Manual • Developing Science Protocol FY08 w/Office of Science • Geologic characterization, site development and operations, risk assessment and mitigation strategies, implementation, outreach,… • Evolve into BMP as research continues

16. Monitoring, Mitigation, and VerificationTechnologies & Protocols Are Emerging

17. Infrastructure ? • Put “first of kind” projects in place • Develop protocols & best practices • Regional Carbon Sequestration Partnerships

18. DOE’s Sequestration Program Structure Infrastructure Core R&D 7 Regional Partnerships • Engage regional, state, local governments • Determine regional sequestration benefits • Baseline region for sources and sinks • Establish monitoring and verification protocols • Address regulatory, environmental, & outreach issues • Validate sequestration technology and infrastructure Carbon Sequestration Leadership Forum Monitoring, Mitigation, & Verification Capture of CO2 • Storage • Direct CO2 storage • Enhanced natural sinks Non-CO2 GHG Mitigation IntegrationProjects Break- through Concepts

19. Regional Carbon Sequestration Partnerships • Representing: • >350 Organizations • 41 States • 4 Canadian Provinces • 3 Indian Nations • 34% cost share Creating Infrastructure for Wide Scale Deployment Characterization Phase • 24 months (2003-2005) Validation Phase • 4 years (2005 - 2009) • 7 Partnerships (41 states) • 25 Geologic field validation tests Deployment Phase • 10 years (2008-2017) • Several large injection tests in different geology

20. Northwest Alberta Formation Type Oil bearing Gas bearing Saline formation Coal seam Partnerships MRCSP MGSC SECARB SWP WESTCARB Big Sky PCOR 13 12 14 11 17 18 16 15 23 7 24 8 25 9 10 5 6 4 19 3 21 2 20 1 22 Phase II Field Validation25 Geologic Tests • MMV technologies • Permitting requirements • Public outreach • Injections 750-525,000 Tons CO2 • Larger in conjunction with EOR • Validating geologic formation capacities and injectivity • Testing formation seals

21. - Baseline - Drilling - Injection - MMV

22. Phase III Timeline Site selection and characterization; Permitting and NEPA compliance; Well completion and testing; Infrastructure development Years 1-3 CO2 procurement and transportation; Injection operations; Monitoring activities Years 4-7 Site closure; Post injection monitoring; Project assessment Years 8-10 Deployment PhaseScaling Up Towards Commercialization • FY 2008-2017 (10 years) • Several Large Volume Sequestration tests in North America • Injection rates up to 1,000,000 tons per year for several years • Scale up is required to provide insight into several operational and technical issues in different formations

23. Large Scale Test Locations as of 2/8/2008 PCOR Fort Nelson CO2 Acid Gas Injection Project PCOR Williston Basin CO2 Sequestration and EOR Test MGSC Large-Volume Sequestration Test with Ethanol Plant Source SWP Deep Saline Deployment Project SECARB Phase III Saline Formation Demonstration 1. Early Test 2. Anthropogenic Test - Test Location - Partnership Headquarters

24. Deployment PhaseOutcomes • Site characterization requirements • Storage capacity assessment • Design criteria • Injection wells • Regional monitoring, mitigation, and verification program • Site Closure • Permitting requirements • Validate reservoir and risk assessment models • Accelerate public outreach • Science Protocols • Best practice manuals

25. Visit Office of Fossil Energy & NETL Websites http://fossil.energy.gov/ http://www.netl.doe.gov