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Perspectives on CO2 and Mercury Reduction

Portland Cement AssociationMeeting of the Manufacturing Technical Committee

Chicago, Illinois

Steve Benson

September 10, 2007

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About the EERCAbout the EERC

• Cleaner, more efficient energy technologies.

• Air, water, and soil pollution prevention and cleanup.

• Water management.• Waste management/remediation.• Advanced power and energy

systems.• Renewable energy.• Advanced analytical methods.• Education and training.

The EERC is a research, development, demonstration, and commercialization facility recognized internationally for its expertise in:

““The EERC is a firstThe EERC is a first--class organization, with highly motivated and class organization, with highly motivated and experienced professionals and techniciansexperienced professionals and technicians……One of the bestOne of the best——or the or the bestbest——R&D facilities in the United States and the worldR&D facilities in the United States and the world……..””

——U.S. Department of Energy evaluation reportU.S. Department of Energy evaluation report

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EERC ClientsEERC Clients

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EERC Quick FactsEERC Quick Facts• Total value of current EERC contract portfolio is over $151 million.• Since 1987, the EERC has had nearly 1000 clients in 49 countries and all 50

states.• In FY07, 64% of clients were repeat customers, and more than 93% of

contracts were with nonfederal clients.• The multidisciplinary team has nearly 300 highly skilled scientists, engineers,

and support personnel.• Current facilities include more than 245,000 square feet of laboratory,

demonstration, and office space.• The EERC had 442 active contracts in FY07.• The EERC sends out an average of one funding proposal a day.• Total contract awards in FY07 were over $33 million.• Total expenditures for FY07 were more than $27 million, with an

estimated regional economic impact of $94.5 million.• Fourteen spin-off companies have evolved from EERC programs.

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Research and DevelopmentResearch and Development

• The EERC conducts applied research and development on behalf of its clients—client involvement ensures market focus.

• The EERC maintains a broad range of cutting-edge laboratories and equipment for solid, liquid, and gas processing and characterization of natural and synthetic materials.

• The scale of EERC R&D facilities accommodates samples in sizes from less than a gram to those transported by railcar.

• The EERC is equipped to conduct sampling and analyses in remote locations: “bringing the laboratory to the field.”

• The EERC is committed to practical experimental design and the development of new analytical methods.

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Technology DemonstrationTechnology Demonstration

• The EERC has significant expertise, capabilities, and partnerships to move technologies into and through the demonstration phase with great success.

• The EERC has over 54,000 square feet of demonstration facilities focused on the combustion and gasification of solid and liquid fuels such as coal, biomass, sewage sludge, and oil slurries.

• The seven existing pilot-scale units focus on operational issues and environmental emission controls.

• Additional space is available for testing a variety of industry pilot-scale components.

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Technology CommercializationTechnology Commercialization

• The EERC practices a philosophy that emphasizes true working partnerships between industry, government, and the research community.

• Partnerships with industry are present from the beginning—from the most basic initial work—to technology commercialization.

• The EERC is committed to the commercialization and deployment of promising new technologies.

The revolutionary Advanced Hybrid™ filter technology, developed by the EERC in partnership with W.L. Gore & Associates and DOE, was successfully demonstrated at Otter Tail Power Company’s Big Stone Power Plant in South Dakota.

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Program AreasProgram Areas

• Advanced Power and Energy Systems

• Energy Conversion System Optimization

• Environmental Chemistry

• Environmental Control Technologies

• Fossil Energy Resources (oil, gas, and coal)

• Hydrogen Production, Distribution, and Fuel Cell Technology

• Renewable Energy

• Waste Utilization, Management, and Site Remediation

• Water Management (availability, contaminant remediation, and flood and drought protection)

The EERC is focused on solving the energy and environmental challenges that the world faces today and tomorrow. The EERC has at its foundation nine primary areas of focus as listed below:

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Presentation OverviewPresentation Overview

• CO2– Separation and capture technology overview– Plains CO2 Reduction (PCOR) Partnership

Program– Application to cement industry

• Mercury control– Technologies– Status of regulations and implementation

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U.S. Department of Energy (DOE) Climate U.S. Department of Energy (DOE) Climate Change Technology ProgramChange Technology Program

Source: www.netl.doe.gov/technologies/carbon_seq/index.html

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COCO22 Source CaptureSource Capture

Source: U.S. Department of Energy (DOE) (http://www.netl.doe.gov/coal/Carbon%20Sequestration/partnerships/index.html)

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PostcombustionPostcombustion

Source: Assessment of Carbon Capture Options for Power Plants. By Massoud Rostam-Abadi, Shiaoguo Chen, and Yongiqi Lu

ESP FGD CO2captureESP FGD CO2capture

Postcombustion

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PrecombustionPrecombustion


Precombustion

Shift reactor

CO2 capture

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OxycombustionOxycombustion

ESP FGD

Ash Sulfur

ESP FGD

Ash Sulfur

Oxycombustion


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Chemical Looping

Chemical Looping

CO2HydrateCO2

Hydrate

Microbial/Algae

Microbial/Algae

Electro-chemical

Pump

Electro-chemical

Pump

Others

Chemical(TSA)

Chemical(TSA)

ZeolitesACs

Physical(PSA,TSA)Physical

(PSA,TSA)

Metal Oxides

Si/Al Gels

Inorganic MembraneInorganic Membrane

Metallic

PolysulphonePolyamide

Organic MembraneOrganic

Membrane

CeramicsOthers

Cellulose derivativesOthers

Caustics

RectisolOthers

Physical Physical

Selexol

Amines

Others

ChemicalChemical

Absorption Absorption CryogenicsCryogenics Others Others AdsorptionAdsorption MembranesMembranes

Modified aftere: Assessment of Carbon Capture Options for Power Plants. By Massoud Rostam-Abadi, Shiaoguo Chen, and Yongiqi Lu

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COCO22 Capture and Separation Capture and Separation TechnologiesTechnologies

Combustion Modification Technologies

Gas Adsorption

Gas Absorption Membranes

Gas Separation Membranes

Cryogenic Cooling

Sulfinol, Selexol, Rectisol, Purisol, Catacarb, Benfield, Gas Absorption

Combustion Modification Technologies

Gas Adsorption

Gas Absorption Membranes

Gas Separation Membranes

Cryogenic Cooling

Sulfinol, Selexol, Rectisol, Purisol, Catacarb, Benfield,

oxygen combustion, regenerative carbonate process, chemical-looping combustion, ZEC technology, unmixed fuel processor, ion transport membranes, CO2 hybrid process, water cycle, Graz cycle, MATIANT cycle

alumina, zeolite, activated carbon, electrical swing adsorption, sorption -enhanced water –gas shift process

Kvaerner hybrid membrane system

Molecular Gate membrane, CO 2-selective membrane, hydrogen membrane reformer, membrane water –gas shift reactor, palladium membrane reactor, hybrid alumina/organosilane membrane, thermally optimized polymer membrane, inorganic nanoporous membrane

amines, potassium carbonate/piperazine, Aqua Ammonia process, PSR solvents, alkali carbonate, amine-enriched sorbents, warm gas sodium -based solid sorbents , CO2 hydrate process

oxygen combustion, regenerative carbonate process, chemical-looping combustion, ZEC technology, unmixed fuel processor, ion transport membranes, CO2 hybrid process, water cycle, Graz cycle, MATIANT cycle

alumina, zeolite, activated carbon, electrical swing adsorption, sorption -enhanced water –gas shift process

Kvaerner hybrid membrane system

Molecular Gate membrane, CO 2-selective membrane, hydrogen membrane reformer, membrane water –gas shift reactor, palladium membrane reactor, hybrid alumina/organosilane membrane, thermally optimized polymer membrane, inorganic nanoporous membrane

amines, potassium carbonate/piperazine, Aqua Ammonia process, PSR solvents, alkali carbonate, amine-enriched sorbents, warm gas sodium -based solid sorbents , CO2 hydrate process

Gas Absorption

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Regional Carbon Regional Carbon Sequestration PartnershipsSequestration Partnerships

What Is Our Region Doing?What Is Our Region Doing?

SKAB

BC

MB

MT ND

NE

MO

MN

WI

IA

SD

Nine states and four provinces1,362,089 square miles

The PCOR Partnership has brought together the key stakeholders to make geologic CO2 sequestration a near-term reality.

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The PCOR Partnership currently has over 65 partners representingThe PCOR Partnership currently has over 65 partners representing public public agencies, utilities, oil and gas companies, engineering firms, aagencies, utilities, oil and gas companies, engineering firms, associations ssociations

and nonprofit organizations, and universities. and nonprofit organizations, and universities.

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PCOR Partnership Phase I Major PCOR Partnership Phase I Major ObjectivesObjectives

• Characterize CO2 sources, sinks, and storage options

• Identify issues for technology deployment

• Develop public involvement and educational programs

• Identify the most promising capture and sequestration options

• Prepare action plans for implementation and technology validation activities

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Sources

1225 stationary sources

Total CO2 emissions: ≈ 559 million tons/yr

Electricity Generation (66%)

Paper and Wood Products(6.1%)

Petroleum and Natural Gas Processing (5.2%)

Ethanol Production (4%)

Petroleum Refining (3.2%)

Cement/Clinker Production (2.1%)

All Others (agricultural processing, industrial/institutional heat and power, manufacturing, etc.) (13.4%)

IA

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COCO22 Emissions by Source Type Emissions by Source Type (stationary)(stationary)

Electricity Generation67.1%

Paper and Wood Products

6.0%

Petroleum and Natural Gas Processing

4.9%

Petroleum Refining 2.7%

Ethanol Production

2.8%

Cement/Clinker Production

2.4%

All Others14.1%

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Defining the Sources in the PCOR Defining the Sources in the PCOR Partnership RegionPartnership Region

Oil Fields6000+ fields evaluated

Fields in the Williston, Powder River, Denver–Julesberg, and Alberta Basins were evaluated.

Used two methods:enhanced oil recovery (EOR) and volumetric

• EOR approach: Evaluated ~ 160 fields.

Sequestration capacity = 1 billion tons

Incremental oil>3 billion bbls

• Volumetric approach: Thousands of fields, totalcapacity >10 billion tons.

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Coal Fields

Evaluated Wyodak–Anderson, Ardley, and Harmon–Hanson coals.

CO2 sequestration capacity estimated to date: >8 billion tons

17 Tcf of methane potential from enhanced coalbedmethane (ECBM) in these seams.

Don’t need supercritical CO2, and purity of stream isn’t an issue (significant N may be good).

ND

Estimates based on data provided by states, provinces, and USGS.

Ardley estimates by Bachu, EUB.

Other estimates by Nelson, EERC.

SKAB

BC

MB

MT

SD

NE

MO

MN

WI

Ardley Coal

Harmon-Hanson Coal

Wyodak-Anderson Coal IA

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Estimated Regional Sequestration Estimated Regional Sequestration CapacitiesCapacities

1,409 million tons CO2/yrTotal

49 million tons CO2/yrPeat Bogs

261 million tons CO2/yrAgricultural Lands (crop-, range-, and grasslands)

55 million tons CO2/yrWetlands

1,044 million tons CO2/yrForests

Terrestrial Sinks

241,380 million tons CO2Total

3,200 million tons CO2Oil and gas fields in Alberta, Manitoba, and Saskatchewan

10,000 million tons CO2EOR in selected oil fields

380 million tons CO2North Dakota lignite deposits

6,800 million tons CO2Powder River Basin coal seams

161,000 million tons CO2Lower Cretaceous saline aquifer system

60,000 million tons CO2Mississippian Madison saline aquifer system

Geologic Sinks

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PCOR Partnership Decision Support System (DSS)PCOR Partnership Decision Support System (DSS)

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Matching SourceMatching Source––Technology Pairs to Technology Pairs to Geologic SinksGeologic Sinks

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Public OutreachPublic Outreach

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Phase II Goals • Increase public understanding of CO2 sequestration• Perform field validation tests that develop:

- Monitoring, mitigation, and verification(MMV) protocols.

- Regional sequestration strategies.- Best separation/source matches.- Regulatory and permitting strategies.- Environmental benefits and risks.- Information needed to monetize C credits.

• Continued regional characterization. • Creating a vision for practical environmentally sound carbon management strategies.

PCOR PartnershipPCOR Partnership

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PCOR Partnership Phase II ObjectivesPCOR Partnership Phase II Objectives

• Four CO2 sequestration demonstrations will be performed:

– Injection into a deep carbonate reservoir for EOR

– Injection of acid gas (about 30 wt% H2S) into a pinnacle reef for EOR

– Injection into a lignite seam for ECBM recovery

– Terrestrial field validation and quantification in Prairie Pothole Wetlands

• Regional characterization and DSS development will continue.

• Safety, regulatory, and permitting issues will be researched.

• Public outreach and education will continue with fact sheets, television programs, and booths/presentations.

• Commercially available sequestration technologies ready for large-scale deployment will be identified.

PCOR Partnership Phase II PCOR Partnership Phase II –– Regional Regional Field Verification ActivitiesField Verification Activities

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Zama, AlbertaZama, Alberta

CO2-rich gas in a pinnacle reef structure –Results will help to determine the best practices to support sequestration in these unique geologic structures as well as further our understanding of the effects of H2S on tertiary oil recovery and CO2sequestration.

Williston Basin Oil FieldWilliston Basin Oil Field

• CO2 in a deep oil reservoir –CO2 will be injected into an oil-bearing zone.

• We are currently finalizing plans with Hess Corporation for this summer’s field-based activities.

• Sharing Eclipse models and expertise.

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• CO2 in an unminable lignite seam – CO2 will be injected for both CO2 sequestration and enhanced coalbed methane production.

• State of North Dakota is providing surface and mineral rights access; hoping to drill this summer.

Lignite for COLignite for CO22 Sequestration and ECBM Sequestration and ECBM

Terrestrial DemonstrationTerrestrial Demonstration

Out of the Air – Into the Soil – A managed wetland will be implemented in north-central South Dakota to demonstrate practices that will improve CO2 uptake. The results will help to optimize CO2 storage, monitoring, and verification methods and facilitate the monetization of terrestrial carbon offsets in the region and elsewhere.

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EERC PCOR EERC PCOR Partnership Phase III Goals Partnership Phase III Goals

• Meet or exceed our partners’ expectations – develop a project that leads to commercial success.

• Develop infrastructure and expertise that propagate our region’s competitive advantage into the future.

• Develop public support through outreach and education.• Develop industry standards for MMV.• Develop user-friendly standards for:

– Site selection/permitting– Risk assessment– MMV

• Develop markets and standards for the monetization of carbon credits.

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We Are Evaluating Two Phase III EffortsWe Are Evaluating Two Phase III Efforts

Saline Formation Injection in Canada

A Williston Basin Project

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Williston Basin Phase III Williston Basin Phase III –– PhilosophyPhilosophy

• North American oil production is reaching mature stages, and CO2 is the future of tertiary oil recovery.

• EOR is a bridge technology for future large-scale implementation of CO2 carbon capture and sequestration (CCS).

• There is a tremendous capacity for sequestration in PCOR Partnership region oil fields (>3 billion tons).

• Absent other incentives, the economic component is critical for encouraging the widespread adoption of CCS in the PCOR Partnership region.

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Williston Basin Williston Basin Phase III Phase III –– ConceptConcept

• Capture at least 1 Mt/yr of CO2 at existing coal-fired power plant (CFPP) in central North Dakota.

• Transport via pipeline to Encore oil field in Williston Basin.

• Meet or exceed all of the DOE Phase III objectives.

• Conduct MMV activities to document integrity of storage.

• Ultimately monetize credits.

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Williston Basin Phase III Williston Basin Phase III ––Project BenefitsProject Benefits

• One of the first commercial-scale projects to capture CO2 from a retrofitted CFPP.

• One of the first large-scale implementations of cost-effective MMV plan based on proven industrial technology applications and regulatory processes.

• Utilization of existing technologies, methodologies, and frameworks to adapt existing regulatory processes for large-scale CCS.

• Develop supporting evidence for the hypothesis that effective MMV need not be intrusive to field operations nor expensive to implement.

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Fort Nelson Fort Nelson Carbon Capture and Carbon Capture and

Sequestration Sequestration in a Deep Saline in a Deep Saline

AquiferAquifer

Spectra Energy Transmission

Fort Nelson Gas Plant, British Columbia, Canada

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A Critical Component of North A Critical Component of North AmericaAmerica’’s Energy Futures Energy Future

BuckinghorsePlant

SikanniPlant

Jedney Plants

Chetwynd

Aitken Ck.Plant

Boundary Lake PlantFort

St. John

HighwayPlant

TCPL/Nova

Fort Nelson

B.C.

YukonN.W.T.

CS 2

SET Processing Plant

Compressor Stn.

BC Pipeline Mainline

Gathering Lines

Spectra Energy Transmission:

Kwoen Plant

Fort LiardLegend

Mainline Looping

Gordondale

Fort St. JohnArea

Fort St. JohnArea

Booster Stn.

Grizzly ValleyArea

Grizzly ValleyArea

Alliance

FortNelsonPlant

PineRiverPlant

B.C.

ALB

ERTA

N.W.T.YUKON

U.S.A.

McMahonPlant

Alaska Highway

Dawson Creek

Fort NelsonArea

Fort NelsonArea

SEIF Midstream Plant

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Research Safety, Regulatory, and Research Safety, Regulatory, and Permitting IssuesPermitting Issues

• Interstate Oil and Gas Compact Commission (IOGCC)– Carbon Capture and Geological Storage

Regulatory Task Force • Developing model regulations dealing with site

licensing, well operation, well/site closure, and long-term storage.

– Utilizes existing expertise and legal precedents– Already being adopted/considered by several U.S. states

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Philosophy of MMVPhilosophy of MMV

• MMV activities for oil field sequestration should:– Maximize the use of existing data sets to develop background

and baseline conditions.– Minimize the use of invasive or disruptive technologies to

acquire new data.– Coordinate MMV data acquisition with routinely scheduled

operational data acquisition activities. • Use resources to qualify “good” sites, not monitor “bad” sites.• More isn’t necessarily better:

– Seismic techniques have severe technical and economic limitations.

– Monitoring wells or migration pathways?– If surface monitoring is a key component of MMV, you have likely

picked the wrong site (obviously still a key safety protocol).

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MMV Includes MMV Includes Baseline CharacterizationBaseline Characterization

• Geology• Hydrogeology• Geomechanics• Reservoir• Cap rock and seal• Production history• Water injection history

Baseline characterization for demonstration sites should be done at small (field), medium (subbasin), and large (basin) scales.

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Core MMV TechnologiesCore MMV Technologies

• Rock core collection and analyses.

• Well logs (historic and new).

• Observation wells.

• Introduction of tracers for leak detection.

• Periodic fluid sample analyses from reservoir and overlying formations.

• Plume behavior modeling.

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Geologic COGeologic CO22 StorageStorageCredit MonetizationCredit Monetization

A common accounting framework is needed to monetize carbon credits for geological CO2 sequestration.

Framework must be based on:

• Detailed characterization.• Sound engineering design.• Cost-effective MMV.• Equitable legal and regulatory process.

Unitization process for oil fields may be suitable model for such a framework.

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Basics of Oil Field UnitizationBasics of Oil Field Unitization

Unitized fieldsNonunitized fields

For oil fields with multiple operators, unitization is needed to:

1. Implement secondary and tertiary EOR projects within an established field.

2. Ensure coordinated fluid injection and production.

3. Protect correlative mineral rights.

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Additional Comments about Geological Additional Comments about Geological Sequestration UnitsSequestration Units

The geological sequestration units concept facilitates monetization.

• Formal process provides level of certainty with respect to project development.

• Ensures technical, economic, legal, and social issues are formally incorporated into the decision-making process.

• Provides a standardized mechanism for making critical information available to carbon credit buyers, sellers, and appraisers.

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Carbon Management Carbon Management Key QuestionsKey Questions

• Do we need to look beyond enhanced recovery projects in the near term?

• How important will retrofits for CO2 capture be relative to new facilities?

• How will infrastructure be financed and managed?• What will control the economics? It will be a

combination of enhanced recovery potential, regulation, incentives, taxes, and other factors.

• What about carbon markets?• Will carbon management become a key element of

energy production?

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Cement KilnsCement Kilns

Twelve cement kilns in the PCOR Partnership region produce 12.5 million short tons CO2/yr, which is 2.4% of the region’s emissions.

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Cement Kilns and Sinks in the RegionCement Kilns and Sinks in the Region

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AlbertaAlberta’’s Cement Kilnss Cement Kilns

Three kilns produce 2.3 million short tons of CO2/yr.

Geologic sink capacity in the vicinity is >500 million tons in the oil fields and >800 million tons in the Ardley coal zone.

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Example: Edmonton KilnExample: Edmonton Kiln

Production = 2131 tons CO2/day (34,761 Mcf)

EOR projects typically require about 8 Mcf of CO2/barrel of incremental produced.

If all of the CO2 generated by the kiln were used for EOR, over 4700 barrels of oil could be produced/day.

At an oil price of US$60/barrel, the total value would be about US$282,000/day, or nearly US$103 million annually.

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Amine ScrubbingAmine Scrubbing

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Capture and Separation CostsCapture and Separation Costs

The cost of capturing and separating CO2 from cement kiln gases using amine scrubbing has been estimated to range from $50 to $54/short ton. This includes $9 to dehydrate and compress the gas to pipeline pressures of roughly 1500 psi to 2100 psi.

Assuming that carbon offsets and sale of the CO2 are options, the net cost to a facility could range from about $36/short tonsin the United States (where the CO2 credit market is just being developed) to $11/short tons in Canada (assuming European credit market prices).

Sale of CO2 for EOR is a market that is likely to decrease. Companies that act reasonably quickly on the opportunity to produce CO2 for sale will benefit the most.

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Possible COPossible CO22 Sequestration Cost Offsets for Sequestration Cost Offsets for the Cement Industrythe Cement Industry

• Carbon credit trading could offset CO2 capture costs.

• Development of breakthrough capture techniques would reduce the costs.

• Integrating capture technologies into cement production or modifying processing methods might reduce capture costs.

• CO2 stream could be sold for EOR, ECBM, or for use in the food industry.

• Community goodwill could be generated by addressing greenhouse gas emissions and global warming.

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ConclusionConclusion

Through capture technology development and/or implementation as well as carbon credit trading, sequestration of CO2 from cement kilns offers the opportunity to enhance corporate image through greenhouse gas emission reduction while simultaneously creating a potential revenue stream.

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Partnership BenefitsPartnership BenefitsWe are currently looking for any additional parties

interested in joining the PCOR Partnership.

By becoming a PCOR partner you will have timely access to developments and lessons learned at the regional and national level with regard to sequestration and other evolving strategies to reduce

CO2 emissions in a cost-effective manner; research topics and demonstrations such as:

• Characterization of Regional Sequestration Opportunities• Safety, Regulatory, and Permitting Issues• Public Outreach and Education• Identification of the Commercially Available Sequestration

Technologies Ready for Large-Scale Deployment• Regional Partnership Program Integration

Partnership Benefits (cont.)Partnership Benefits (cont.)

• Access to “Partners Only” data and information on regional CO2sources, sequestration options, regulatory assessments, environmental issue assessments, and project modeling.

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• Access to the PCOR Partnership DSS, shown below. The DSS is a Web-based GIS system that contains detailed information with regard to the major stationary CO2sources and sinks in the region.

Examples of regional information prepared in Phase I of the PCOR Partnership are shown in the next four slides (sources, oil fields, coal fields, sedimentary basins)


• Regular contact with others in the region and at the national level who have a stake in developing efficient and environmentally sound options for sequestration.

The PCOR Partnership is bringing together the stakeholdersneeded to make CO2 sequestration a viable option for carbon management in our region.

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Partnership Benefits (cont.)Partnership Benefits (cont.)• Information on events, conferences, and workshops

PCOR Partnership Phase I Wrap-Up/Phase II Kickoff Meeting was held at the Xcel Energy Corporate

Headquarters November 1–2, 2005, in Minneapolis, MN.

PCOR Partnership 2006 Annual Meeting, Calgary, Alberta, Canada held at the Delta Bow Valley Hotel September 13–15, 2006, in Alberta, Calgary, Canada

5th Annual Conference on Carbon Capture & Sequestration, May 8–11, 2006, Alexandria, Virginia

Partnership Benefits (cont.)Partnership Benefits (cont.)Access to research materials (deliverables), including:

• Regional atlas• Road map documents• Fact sheets• Topical reports • Quarterly reports• Design packages• Sampling protocols• Outreach action plans • Progress reports• Site health and safety plans• Video documentaries• Regional characterization gap assessment• National Environmental Policy Act (NEPA) compliance forms• Regional permitting implementation outlines• Project management plans• Regulatory permitting action plans

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Nature in the Balance – CO2 Sequestration” is a 30-minute documentary produced for general audiences with Prairie Public Television on CO2sequestration, NETL’s Regional Carbon Sequestration Partnership program, and

PCOR Partnership region activities. There will be a series of four documentaries over the course of Phase II:

• Carbon Markets and Carbon Trading (Spring 2007)

• Terrestrial CO2 Sequestration(Winter 2008)

• Geologic CO2 Sequestration(Summer 2008)

• CO2 Sequestration and Global Warming – Overview of Phase II Results from NETL’s Regional Partnership (Spring 2009)

These documentaries are aired on Prairie Public Television, and made available to other public television stations nationally. The use of the broadcasts will be

optimized by offering DVDs of the television productions and streaming video on the Web site. In addition, press releases and newspaper articles will be tied in to

optimize public awareness as well as the impact of the broadcast.

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The PCOR Partnership Atlas provides a general overview of CO2 sequestration. It also provided a graphic summary of major CO2 sources and sinks in the PCOR Partnership region.

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PCOR Partnership Vision Assumptions PCOR Partnership Vision Assumptions

• We need abundant and affordable energy to sustain healthy lives.

• The developing world needs abundant and affordable energy too.

• We are likely moving toward a world where carbon management will be increasingly important.

• In order to significantly reduce CO2 emissions we need to move into CO2 sequestration.

For more information on the PCOR Partnership, please contact:For more information on the PCOR Partnership, please contact:

Ed SteadmanEd Steadman(701) 777(701) 777--52795279

[email protected]@undeerc.org

Steph WolfeSteph Wolfe(701) 777(701) 777--52295229

[email protected]@undeerc.org

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Mercury Control Mercury Control ––

Summary and Future DirectionsSummary and Future Directions

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Clean Air Mercury Rule (CAMR)Clean Air Mercury Rule (CAMR)

Hg AllocationBituminous – 1.0

Subbituminous – 1.25Lignite – 3.0

Subcategory Factors

Continuous Hg monitoring required

Monitoring

Phase I 10 tons/yr (20.8%)Phase II 33 tons/yr (68.8%)

Mercury Reduction

Phase I 2010Phase II 2018

Compliance Date

48 tons/yrCurrent Mercury Emissions

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Summary of Emission ReductionsSummary of Emission ReductionsUsing CapUsing Cap--andand--Trade ApproachTrade Approach

Reduce 1.7 Mtpy for a 53% reduction from 2003 levels

2009

Reduce an additional 0.3 Mtpy for a 61% reduction from 2003 levels

NOx*

Reduce an additional 1.1 Mtpy for a 57% reduction from 2003 levels

Reduce 4.3 Mtpy for a 45% reduction from 2003 levels

SO2*

Cap at 15 tpy,69% reduction from 48 tpy

Cap at 38 tpy,21% reduction from 48 tpy

Hg

201820152010

*Expected nationwide reductions based on EPA modeling.

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• Mercury emissions regulated by either:– Existing Clean Air Act – (Section

112) – Clean Air Mercury Rule

– State-prescribed limits that are more stringent

– Approximately 60%–90% reduction necessary in 2009–2015 time frame

Mercury RegulationsMercury Regulations

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Oregon

CO

AZ

PAIL

MA

VA

CT

MD

MEMNMT

NJ

Washington

Wisconsin

California

Florida

Indiana

Michigan

Delaware

Rhode IslandNew York

Ohio

Georgia

North Carolina

South Carolina

New Mexico

Texas

State Regulations Driving Mercury State Regulations Driving Mercury Control Technology ImplementationControl Technology Implementation

State with firm regulations more strict than CAMR (12)State with proposed regulations more strict than CAMR (13)Plants with consent decree limiting Hg emission

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Mercury TransformationsMercury Transformations

Hg2+ X(g) SpeciesHg(NO3)2HgO

Hg0(g)

HgCl2(g)

Chlorination

Cl/HCl/Cl2NO/NO2

SO2/SO3 Hg0

Fuel

Sorption

Postcombustion

HgCl2(g)

CatalyticOxidation

Hg(p) SpeciesHgCl2HgOHgSO4HgSHgSeCarbonAssociationsHgFeOxide

Combustion

VaporizationAsh Formation andParticle Growth

AuHgAgHg ..

Amalgam

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ThermocoupleThermometer

HeatedProbe

Pitot

StackWall

GlassProbeLiner

GlassFilter

Holder

HeatedArea

Manometer

Orifice

DryGas

Meter

Air-TightPump

MainValve

BypassValve

VacuumGauge

VacuumLine

Silica Gel

IceBath

Thermometer

CheckValve

5% HNO /10% H O3 2 2

10% H SO /4% KMnO2 4 41N KCI Solution in H O2

Ontario Hydro Impinger TrainOntario Hydro Impinger Train

Complete CMM PackageComplete CMM Package

• Probe

• Pretreatment/conversion system

• Calibration system

• Mercury analyzer Tekran

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Mercury Control OptionsMercury Control Options

Baghouseor

ESPScrubber

Boiler

SorbentInjection

Stack

Sorbent Bed

Cleaning ChemicalOxidation

CatalyticOxidation

SCR

Cat

alys

t

Capture/Recover/Regenerate

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• Energy efficiency and conservation – Improved plant generation

efficiency – Improved-efficiency consumer

products – Energy use conservation

• Demand-side management – Peak power management

programs – Green power programs

• Fuel blending– Natural gas– Oil– Biomass– Petroleum coke– Coal blending– Tire-derived fuel

• Fuel switching– Switching to a mercury-

compliant coal– Repowering with natural gas– Repowering with residual or

distillate oil– Switching to biomass

• Fuel cleaning or pretreatment– Conventional

• Noncombustion sources– Nuclear and hydroelectric– Wind and solar

• Activated carbon injection• Conventional scrubber

technology

• Advanced coal cleaning/pretreatment– K-Fuel process– GRE fluid-bed drying process– Western Research Institute (WRI)

drying process– EERC hydrothermal techniques

• Combustion modifications– GE EER – process and system to

reduce mercury emission by combustion modification

– Lehigh University – increased loss on ignition (LOI)/temperature modifications

– DOE NETL – thief process for the removal of mercury from flue gas

• Treated activated carbons– Sulfur-impregnated carbons– Halogenated carbons

• Iodine-impregnated carbons• Brominated carbons• Chlorinated carbons

• ALSTOM – Mer-CureTM

• Sorbent enhancement additives• Noncarbon sorbents

– Sodium tetrasulfide (Na2S4)– Amended silicates – Calcium-based sorbents

• Fixed sorbent (carbon) beds • EPRI MerCAP™• Mercury oxidation technologies for wet FGD

applications• Oxidation/scrubber technologies• ChemMod

• Advanced cleaning/separation– Magnetic separation– Advanced froth flotation– Selective agglomeration– Chemical methods– Biological methods

• Novel sorbents– Metal oxide-based sorbents

• Noncarbon fixed beds • Mercury control with the Advanced Hybrid™

filter• W.L. Gore & Associates, Inc., promoted felt

filter bag inserts• Pahlman Process (EnviroScrub)• Airborne Process – sodium bicarbonate

scrubbing• Advanced dry scrubbing• LoTox™ – Combined oxidation of NOx and

mercury• PowerSpan – Electrocatalytic oxidation

(ECO™)• DOE NETL – Photochemical oxidation (PCO™) • McDermott Technology Inc. – condensing

heat exchanger

Commercially Promising

Mercury Control Technologies forMercury Control Technologies forCoalCoal--Fired Power PlantsFired Power Plants

Commercially Emerging Developing Technologies

41

81

Particulate Control Particulate Control –– ESP and ESP and Fabric FiltersFabric Filters

82

Comparisons Between Standard and Comparisons Between Standard and Treated Carbons Treated Carbons –– ESPESP

ESP Field Test

0102030405060708090

100

0 2 4 6 8 10

PAC Injection Rate (lb/ Macf)

Mer

cury

Rem

oval

(%)

Brayton Point Darco Hg

Salem Harbor Darco Hg

Yates #1 Darco Hg

Yates #2 Darco Hg Full F.G.CondYates #1 Super HOK

Leland Olds SEA 0

Leland Olds SEA1 300ppm

Leland Olds SEA 2 50 ppm

St Clair BPAC

Comparisons with Data from DOE NETL Web Site

42

83

Hg Removal at LOS Using EERC Hg Removal at LOS Using EERC Slipstream FF*Slipstream FF*

0

10

20

30

40

50

60

70

80

90

0 0.5 1 1.5 2 2.5

ACI (lb/MMacf)

Hg

Rem

oval

(%)

*The prior addition of chlorine may have improved results.

Slipstream Testing

84

0 1 2 3 4 50

10

20

30

40

50

60

70

80

90

100

0

10

20

30

40

50

60

70

80

90

100

Norit LH EERC C3PO Norit Hg Luscar 4 EERC C2HO Luscar 2 Luscar 3 Aquasorb BP-2 Aquasorb BP-5

Mer

cury

Ca

ptu

re, %

A C R ate , lb /M acf

ECRF ACI Upstream of FFECRF ACI Upstream of FF

43

85

Dry Scrubbers Dry Scrubbers –– Spray DryerSpray Dryer––Fabric FiltersFabric Filters

86

Comparisons Between Standard and Treated Comparisons Between Standard and Treated Carbons Carbons –– SDASDA––FFFF

FF Field Test Results 2001-2004

0102030405060708090

100

0 2 4 6 8

PAC Injection Rate (lb/ Macf)

Mer

cury

Rem

oval

Effi

cien

cy, % Holcomb Hg-Lh

Holcomb Darco Hg

Stanton 10 Hg-Lh(halogenated PAC)Stanton 10 Darco Hg(PAC)AVS PAC Only

AVS SEA 1 351 ppm(1.4 lb/Macf)AVS Aq SEA 2 19ppm (0.078 lb/Macf)

44

87

SCRs and Wet ScrubbersSCRs and Wet Scrubbers

0.0

2.0

4.0

6.0

8.0

10.0

12.0

14.0

16.0

Mer

cury

Con

cent

ratio

n, μ

g/ds

cm

SCR In

let

APCD In

w/ S

CR

APCD In

w/o

SCR

Stac

k w/ S

CR

Stac

k w/o

SCR

SCR In

let

APCD In

w/ S

CR

APCD In

w/o

SCR

Stac

k w/ S

CR

Stac

k w/o

SCR

Elemental HgOxidized HgParticulate-Bound Hg

Subbituminous Coal

Bituminous Coal

SCR TechnologySCR TechnologyLimited LowLimited Low--Rank Coal DataRank Coal Data

Increased oxidized Hgto downstream emission

control devices

45

89

Mercury Oxidation Across SCR Slipstream Mercury Oxidation Across SCR Slipstream Catalyst Catalyst –– Lignite Lignite –– 4 months4 months

Hg Measurements Across SCR

0.02.04.06.08.0

10.012.014.016.0

SCR Inlet1

SCR Inlet2

SCR Inlet3

OutletAmmonia

On

OutletAmmonia

On

OutletAmmonia

On

Hg

µg/m

3 Particulate

Elemental

Oxidized

90

MRY ESP/Wet ScrubberMRY ESP/Wet ScrubberSEA2 + PAC Stack CMMSEA2 + PAC Stack CMM

Preliminary

Stack CMM Measurements (SEA-ppm, PAC-lb/Macf)

46

91

Work Yet to Be Done: LongerWork Yet to Be Done: Longer--Term Term Testing RequiredTesting Required

• Absence of long-term (1 year or longer) tests raises questions about:– Sustainable Hg control variable plant operation.– Corrosion (boiler additives or enhanced carbons [chemically

treated carbons]).– Potential emissions of additives or impregnation chemicals or

release from ash. – ESP collection efficiency.– Bag life resulting from increased cleaning cycles and/or pressure-

drop increase (usually appears only after 6 to 18 months).– Ash utilization in concrete; potential organo- and elemental

mercury releases from ash used as structural fill or soil amendments.

92

Contact InformationContact Information

Energy & Environmental Research CenterUniversity of North Dakota

15 North 23rd Street, Stop 9018Grand Forks, North Dakota 58202-9018

World Wide Web: www.undeerc.orgTelephone No. (701) 777-5000

Fax No. (701) 777-5181

Steven A. Benson, Ph.D.Senior Research Manager

(701) [email protected]

perspectives on co and mercury reduction - …cement.org/manufacture/pdf/steve benson mtc...

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