Status of North American CO2 Capture and Storage (CCS ... · 2 Capture and Storage (CCS) Projects ... IGCC / 90% (also producing urea / ammonia) $3.9B / $408M (CCPI) Kemper County

Adam Berger Electric Power Research Institute (EPRI)

UKCCSRC Autumn Biannual Meeting 2014

September 11th 2014

Status of North American CO2 Capture and Storage (CCS) Projects

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Overview of Major Projects

• While several North American CCS demonstrations have been cancelled, significant projects are ongoing in all areas

• Most funding came from government grants during the economic stimulus

• Largest CCS projects involving coal flue gas worldwide have occurred in the region; CCS on gas not pursued for now

• All large-scale CCS demonstrations in North America involve enhanced oil recovery (EOR) save FutureGen 2.0; less public concerns about storage than in the EU

• More CCS projects are needed to improve technologies; from where will new funding come?

What is the current status of and future for CCS projects?

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North American CCS Pilots

Project / Location

Owner Size, Net MW

Capture Process / % Capture

Vendor Comment

Mountaineer / West Virginia

AEP 20 Post-combustion capture (PCC) / 75%

Alstom Facility shut down; first to do full CCS on

coal Plant Barry / Alabama

Alabama Power, Southern

25 PCC / 90% MHI Still in operation; first to have significant

transportation Shand / Canada

Saskatchewan Power

7 PCC / 90% Multiple (including Hitachi)

Not operational yet (late 2014); may have storage; will be a test

facility

Significant pilot-scale work has been and is being performed

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Alstom’s Chilled Ammonia Process at AEP’s Mountaineer Property of Alstom Power and/or AEP

Mountaineer

• Alstom’s chilled ammonia CO2 post-combustion capture

– ~20-MW demonstration at AEP’s Mountaineer Plant in WV

– Designed for ~100,000 tonnes-CO2/year; 75% CO2 capture

– Injection occurred in saline reservoir using two on-site wells – Capture started in September 2009 and storage in October 2009;

51,000 tonnes captured and 37,500 tonnes stored – Capture project completed in May 2011, storage monitoring continues

• Experience – Met design goals (75% capture) – Resolved design issues caused by accelerated schedule – Process improvements identified – Storage permitting is challenging and new to regulators – Calculated cost of electricity for commercial-scale plant ~$113–123/MWh

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Plant Barry

MHI’s KM-CDR Process at Plant Barry Property of MHI and/or Southern

• MHI KM-CDR advanced amine CO2 post-combustion capture

– ~25-MW demonstration at Alabama Power’s Plant Barry in AL

– 500 tonnes-CO2/day – Capture started on 3 June 2011;

~200,000 tonnes captured – Injection started on 20 August 2012; ~100,000 tonnes stored in oilfield 20 km away – Plan: Capture CO2 through 2014, then 3 years of post-injection monitoring

• Experience – Capture plant demonstrated stable performance at full load conditions with lower

steam consumption than MHI conventional capture process – New amine emission reduction technologies achieved significant reduction (90%) – Stored CO2 with minimal issues – Significant characterization and monitoring efforts have taken place – Regulatory hurdles for storage were substantial

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North American CCS Demonstrations

Project / Location Owner Size, Net MW

Capture Process / % Capture

Cost / Funding (Source)

Status

Boundary Dam / Canada

Saskatchewan Power

110 PCC (Cansolv) / 90%

$1.4B / $245M (Saskatchewan

govt) FutureGen 2.0 / Illinois

FutureGen Alliance

99 Oxy-combustion / 98%

$1.65B / $1B (ARRA)

Hydrogen Energy California (HECA) / California

SCS Energy 288 IGCC / 90% (also producing urea /

ammonia)

$3.9B / $408M (CCPI)

Kemper County / Mississippi

Mississippi Power / Southern

524 / 582 IGCC / ~65% ? / $270M (CCPI)

Texas Clean Energy Project (TCEP) / Texas

Summit Power 200 IGCC / 90% (also producing urea /

ammonia)

$2.9B / $450M (CCPI)

WA Parish / Texas NRG Energy, Petra Nova

250 PCC / 90% $845M for PCC / $167M (CCPI)

Boundary Dam and Kemper County are moving forward; others are possible

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Boundary Dam

Boundary Dam Used with permission from SaskPower

• World’s first commercial PCC CCS demonstration; expected on-line in late 2014

• Retrofit Boundary Dam Unit 3 – Increase steam to 124 bar, 565oC – Capture ~1 Mtonnes/year CO2

• Net power of 110 MW after capture • Cansolv process captures SO2 & CO2 • Anticipated energy penalty 21% • Delays due to issues on power plant retrofit (asbestos, welding);

CCS unit is done • CO2 for EOR

– Some saline storage during commissioning

Used with permission from SaskPower

CO2 and SO2Absorbers

CO2 StripperFlue Gas from

Plant

Covered Buildings (weather)

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• IGCC with CCS plant nearing completion; expected on-line in late 2014

• 65% CO2 capture for EOR • Two-train plant with air-blown

TRIG gasifiers, Selexol, and Siemens gas turbines / Toshiba steam turbine

• Uses local Mississippi lignite • 524-MW net with peak using duct firing of 582 MW • Design net plant heat rate with CCS 12,353–12,819 kJ/kWh

– 28-29% efficiency

Kemper County Illustration Used with permission from Southern Company

Kemper County

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FutureGen 2.0

• 99-MW net oxy-combustion repower on Meredosia Unit 4 – 98% capture – 1.1 Mtonnes/year storage in

Mt. Simon formation 48 km away • FutureGen Alliance (5 members)

leading project. Major vendors: B&W and Air Liquide

• All permits, financing and power purchase agreement are in place • Air-fired net plant efficiency = 31.5% (HHV) air-fired; 21.5–22.5%

(HHV) oxy-combustion with CCS (lower due to use of existing steam turbines)

• Construction: 2014–17; Operation: 2017–37; Monitoring: 2037–87

FutureGen 2.0 Process Flow Diagram Used with permission from the FutureGen Alliance

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Feedstock Storage

Urea Storage UAN Storage

Power Block Gasifier

Water Treatment

Sulfur Recovery

Fertilizer Complex

Shift Rectisol

Gasifier 100%

Ammonia 60%

Power 100%

Draw Down Storage

Fertilizer 100% 33%

67%

Gasifier 100%

Ammonia 100% Power 65%

Build Storage

Fertilizer 100% 50%

50%

Maximum Power Production (16 hours/day) Maximum Ammonia Production (8 hours/day)

Used with permission from Hydrogen Energy California

HECA – Hydrogen Energy California

Polygeneration with variable operation and two operating modes; Project is in jeopardy due to financial closure issues

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TCEP – Texas Clean Energy Project

Polygeneration with fixed operation and one operating mode; Project is in jeopardy due to uncertainty in off-take agreements

Used with permission from Summit Power

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WA Parish

WA Parish CCS Illustration Used with permission from Petra Nova

• Retrofit PCC to 250-MW unit in Richmond, TX – Recently announced

using MHI amine capture system

– 1.5 Mtonnes for EOR • Gas-fired peaker to provide power + steam for capture unit • 130-km pipeline for EOR • Federal permitting took nearly two years

– Environmental impact statement – no major impacts • Project on a path forward for financial close, plant

construction, commercial operations by 2015

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Summary for North America

• CCS demonstrations have not advanced as fast as planned, but progress is being made

• Key CCS pilots ongoing or successfully completed • Boundary Dam and Kemper are only CCS demonstrations

definitely going forward; several more possible • No major new government funding for CCS forecasted, but

need more public funding and support to advance CCS • Questions:

– Are lower-cost CCS technologies required for more demos? – With low natural gas prices, will coal be phased out? – Will CCS be required for natural gas-powered units?

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