Sequestration Program Overview · What is Carbon Capture and Sequestration? Ocean Capture and storage of CO2 and other greenhouse gases that would otherwise be emitted to the atmosphere

October 2008

Sequestration Program OverviewNational Conference of State Legislatures

July 21,2009Sean Plasynski, PhD

Sequestration Technology Manager

Mostly CO2

CO2

Mostly H2

Mixed Gas Stream

and other gases

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Outline of Presentation

• What is Sequestration

• How does it work

• Key Challenges

• Evidence of why it will work and those who are doing it commercially

• DOE Sequestration Program Addressing Challenges

– Regional Carbon Sequestration Partnerships

• Pictures from sites – what does storing CO2 look like

• Summary

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What is Carbon Capture and Sequestration?

Ocean

Capture and storage of CO2 and other greenhouse gases that would otherwise be emitted to the atmosphere

Terrestrial CaptureCO2 absorbed from air

Point Source Capture

• Power Plants

• Ethanol Plants

• Cement

• Steel

• Refineries

• Natural Gas Processing

Terrestrial StorageTrees, grasses, soils

Geologic Storage

• Saline formations

• Depleted oil/gas

• Unmineable coal

•Other: basalts, shalesSandstone

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Carbon Storage – How does it work?Storage mechanisms vary by target class; generally multiple

processes which improve over time•Physical trapping

••Residual phase trappingResidual phase trapping

••Solution/Mineral Solution/Mineral TrappingTrapping

••Gas adsorptionGas adsorption••For organic minerals only (coals, For organic minerals only (coals, oil shales)oil shales)

1.0 MgCO3

0.2NaAlCO3(OH)2

Source: S Benson, LBNL

5Photo courtesy of www.bellona.org

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Key Challenges to Carbon Capture and Storage

•Capture Technology– Existing Plants– New Plants (PC)– IGCC

•Cost of CCS

•Sufficient Storage Capacity

•Permanence

•Best Practices– Storage Site

Characterization– Monitoring/Verification– Modeling

•Regulatory Framework– Permitting– Treatment of CO2

•Legal Framework– Liability– Ownership

• pore space• CO2

•Infrastructure

•Human Capital

•Public Acceptance (NIMBY NUMBY)

Technical Issues Legal/Social Issues

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Lines of Evidence Suggesting Geological Storage Will Be Secure

• Natural CO2 reservoirs• Oil and gas reservoirs• Natural gas storage• 70 CO2 EOR projects in U.S.• 50 acid gas injection sites in North America• Numerical simulation of geological systems• Current Large-Scale CO2 storage projects

““At least 99%+ retention is likely for well At least 99%+ retention is likely for well selected and managed storage sitesselected and managed storage sites””

Bullets Based on Rubin, CMU; Quote from IPCC Special Report on Carbon Capture & Storage

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Large Geological Storage Projects UnderwayEach Stores > 1 Million Tonnes CO2/yr

Photos from Staoil Website

Sleipner Project- Norway • CO2 removed from natural gas produced

on production platform in North Sea• Injection into saline reservoir under sea• Started 1996

In Salah Gas Plant - Algeria• Injection into saline formation

downdip of gas reservoir• 3 wells• Started 2004

Weyburn – Saskatchewan• EOR project with 50 wells• Uses CO2 from coal gasification plant• Started 2000

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DOE’s Carbon Sequestration Program GoalsDevelop Technology Options That...

• Deliver technologies & best practices that provide Carbon

Capture and Safe Storage (CCSS) with:

– 90% CO2 capture at source

– 99% storage permanence

– < 10% increase in COE

• Pre-combustion capture (IGCC)

– < 35% increase in COE

• Post-combustion capture

• Oxy-combustion

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• Engage regional, state, and local governments• Determine regional sequestration benefits• Baseline region for sources and sinks • Establish monitoring and verification protocols• Address regulatory, environmental, and outreach issues• Validate sequestration technology and infrastructure

Regional Carbon Sequestration Partnerships

Developing the Infrastructure for Wide-Scale Deployment

• 7 Regional Partnerships• 43 States, 4 Canadian Provinces• 350+ distinct organizations

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Regional Carbon Sequestration PartnershipsProgram Phases

CHARACTERIZATIONPHASE

Characterize all RCSP regions for carbon capture and storage opportunities

VALIDATION PHASE

Validate technologies through field testing at selected geologic and

terrestrial site locations

DEPLOYMENT PHASE

Complete large-volume deployment tests of sequestration technologiesthat will help enable future commercial-scale applications

2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 20172003FISCAL YEAR

CHARACTERIZATIONPHASE

Characterize all RCSP regions for carbon capture and storage opportunities

VALIDATION PHASE

Validate technologies through field testing at selected geologic

and terrestrial site locations

DEVELOPMENT PHASE

Complete large-volume development tests of sequestration technologiesthat will help enable future commercial scale applications-

2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 20172003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 20172003FISCAL YEAR

Scale of 100 to 10,000 Tons CO2

Scale of 1,000,000 Tons CO2

$16 M DOE +$ 5 M CS

$120 M DOE + $43 M CS

~$500 million DOE - over $200 million cost share

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North American CO2 Storage Potential (Giga Tons)

140140Oil and Gas Fields

180160Unmineable Coal Seams

12,6003300Saline Formations

HighLowSink Type

Available for download at http://www.netl.doe.gov/technologies/carbon_seq/refshelf/atlasII/atlasII.pdf

U.S. Emissions ~ 6 GT CO2/yr all sources

Hundreds of Years of Storage Potential

National Atlas Highlights (Atlas II) Adequate Storage Projected

Saline Formations

Oil and Gas Fields Unmineable Coal Seams

Conservative Resource

Assessment

Emissions ~ 3.8 GT CO2/yr point sources

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Data current as of April 2009

RCSP Phase II: ValidationSmall-Scale Geologic Field Tests

BSCSPBSCSP

WESTCARBWESTCARB

SWPSWP

PCORPCOR

MGSCMGSC MRCSPMRCSP

SECARBSECARB

1

11

13

19

20

21

22

23

16

8

10

9

18

173

62

15

7

14

Injection Complete

Injection Ongoing

2009 Injection

2010 Injection (Project moved to Phase III)

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Sacramento Valley, Colorado Plateau

Saline WESTCARB

Paradox Basin, Aneth Field, Permian Basin, San Juan Basin

Oil-bearing

Coal seam

SWP

Gulf Coast, Mississippi Salt Basin, Central Appalachian, Black Warrior Basin

Oil-bearing

Saline

Coal seam

SECARB

Keg River, Duperow, Williston Basin

Oil-bearing

Coal seam

PCOR

Cincinnati Arch, Michigan Basin, Appalachian Basin

Saline MRCSP

Illinois BasinOil-bearing

Saline Coal seam

MGSC

Columbia BasinSaline Big Sky

Geologic Province

Formation Type

RCSP

1

32 5

6

7

8 109

11

13

14

1615

1817

19 20

21

22 23

12

12

4

4

Saline formations (3,000 to 60,000 tons)

Depleted oil fields (50 to 500,000 tons)

Coal Seams (200 - 30,000 tons)

Basalt formation(1,000 tons)

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Development Phase (III) Goals• Assess

– Injectivity and Capacity– Storage Permanence – Areal Extent of Plume and Leakage

Pathways

• Develop– Risk Assessment Strategies– Best Practices for Industry

• Engage in Public Outreach and Education

• Support Regulatory Development

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8

7

31

2

4

6

5

9

Partnership Geologic Province Type

Big Sky Triassic Nugget Sandstone / Moxa Arch Saline

MGSC Deep Mt. Simon Sandstone SalineMRCSP Shallow Mt. Simon Sandstone Saline

PCORWilliston Basin Carbonates Oil Bearing

Devonian Age Carbonate Rock Saline

SECARB Lower Tuscaloosa Formation Massive Sand Unit Saline

SWP Regional Jurassic & Older Formations Saline

WESTCARB Central Valley Saline

2009 Injection Scheduled2010 Injection Scheduled2011 Injection Scheduled

1

2

3

4

7

8

6

9

5

RCSP Phase III: DevelopmentLarge-Volume Geologic Field Tests

Nine large-volume testsInjections initiated 2009 – 2011

Injection Well Drilled

Injection Started

Core Sampling Taken

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Lessons Learned CapturedCCS Best Practice Manuals

• Phase II– Monitoring Verification and

Accounting (Issued - Feb 2009)– Site characterization (2010)– Simulation and Risk Assessment

(2010)– Well construction and closure (2010)– Regulatory Compliance (2010)– Public Education (2009)

– Terrestrial Practices (2010)

• Phase III Updates– Updates 2016-17

• Final Guidelines (2020)

BEST PRACTICES for:

First Edition

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Midwest Geological Sequestration Consortium (MGSC) Enhanced Coalbed Methane Test

Drilling CBM wells in central Illinois

Injection Well with Monitoring Equipment at MGSC ECBM Test Site

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Midwest Regional Carbon Sequestration Partnership (MRCSP) Michigan Basin Saline Test

Photo taken of drilling work at Charlton FieldThis picture shows the well actively engaged in injectionMichigan Basin Test Site

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Southeast Regional Carbon Sequestration Partnership (SECARB) Saline Reservoir Field Test – Mississippi

Salt Basin

SECARB-Plant Daniel Site Prep, Pipe Delivery, Drill Rig Setup

More than 30 participants gathered for an Open House at the SECARB Plant Daniel Saline Aquifer Field Test to witness CO2 injection operations first-hand on October 15, 2008

Source: SECARB Partnership Monthly Update – November 2008

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Summary

• CCS has the potential to offset hundreds of years of CO2 emissions in the United States

• Value added sinks (EOR/ECBM) hold significant potential to help develop infrastructure for CCS

• Regional Carbon Sequestration Partnerships are proving CCS throughout most of North America

• Lessons learned from small and large scale field projects will help commercial deployment of CCS technologies

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Visit Office of Fossil Energy & NETL Websites

http://fossil.energy.gov/ http://www.netl.doe.gov