**Attachment 2**

***DOE/NETL Environmental & Water Resources Program***

***Mercury Control Technology R&D Project Fact Sheets***

***Prepared by Department of Energy***

***Office of Fossil Energy***

***and***

***National Energy Technology Laboratory***

***June 2003***

***DOE/NETL Environmental & Water Resources***

***Mercury Control Technology Project Fact Sheet***

**[Full-Scale Testing of Mercury Control Via Sorbent
Injection]{.underline}**

(DE-FC26-00NT41005)

-   **[Objective]{.underline}** Conduct full-scale field demonstration
    testing of sorbent injection technology for the control of mercury
    emissions from coal-fired power plants. The full-scale testing will
    provide design, performance, and cost information which can be used
    for future full-scale commercial applications of the technology.

-   **[Sponsors]{.underline}** The project is funded by NETL and a
    partnership team headed by ADA Environmental Solutions. The
    partnership team includes EPRI, Alabama Power Company, PG&E National
    Energy Group, and Wisconsin Energy along with several others.

-   **[Background]{.underline}** Previous laboratory, bench, and
    pilot-scale studies have shown that powdered activated carbon (PAC)
    injection could be an effective technology for the control of
    mercury emissions from coal-fired power plants. Full-scale testing
    of PAC injection is necessary to demonstrate cost and performance
    for various coal rank and particulate control device combinations.

-   **[Project Description]{.underline}** The full-scale demonstration
    testing is being conducted at the following four power plants:
    Alabama Power's 270 MW E.C. Gaston Unit 3 which burns low sulfur
    bituminous coal and uses a hot-side ESP and Compact Hybrid
    Particulate Collector (COHPAC) fabric filter for particulate
    control; Wisconsin Energy's 600 MW Pleasant Prairie Unit 2 which
    burns a Powder River Basin subbituminous coal and uses a cold-side
    ESP; PG&E NEG's Brayton Point Station which burns low sulfur
    bituminous coal and uses two cold-side ESPs in-series; and PG&E
    NEG's Salem Harbor Station which burns low sulfur bituminous coal,
    uses a cold-side ESP and also a SNCR system for NOx control. The PAC
    injection system used for the tests consists of a bulk storage silo
    and dual pneumatic conveying equipment rated at 750 lb/hr. An Apogee
    Scientific mercury CEM is used for semi-continuous speciated mercury
    measurements during the testing. The testing at each plant includes
    parametric tests using several commercially available PAC products
    at various feed rates and operating conditions followed by a one to
    two week long-term test with a PAC selected from the parametric
    testing.

-   **[Schedule]{.underline}** Project started September 2000 and is to
    be completed in September 2003. Testing at the four sites was
    completed as follows: Gaston in April 2001; Pleasant Prairie in
    November 2001; Brayton Point in August 2002; and Salem Harbor in
    November 2002. The final project report is scheduled for completion
    in August 2003.

-   **[Cost]{.underline}** The total budget cost for the project is
    approximately \$6.8 million. (DOE funding \$4,542,563)

-   **[Status]{.underline}** The field demonstration testing has been
    completed at all four sites.

-   **[Results To Date]{.underline}** The following is a brief summary
    of the results from the field tests:

    -   E.C. Gaston: There was no measurable performance difference
        between the different PACs used during the parametric testing.
        Norit's Darco FGD activated carbon was used for the nine day
        long-term testing. Mercury capture averaged from 87 to 90% with
        a carbon injection rate of 1.5 lbs/MMacf based on three
        short-term Ontario Hydro test results. However, the long-term
        mercury CEM data indicated an average capture of 78% that varied
        from 36% to 90%. Average COHPAC inlet mercury concentration was
        approx. 11 ug/dncm of which 40% was elemental. The carbon
        injection significantly increased the required cleaning
        frequency of the COHPAC baghouse. There was no improvement in
        mercury capture using the spray cooling system.

    -   Pleasant Prairie: Norit's Darco FGD activated carbon was used
        during the three 5 day long-term tests at feed rates of 1.6,
        3.7, and 11.3 lb./MMacf. Mercury capture averaged approx. 46%,
        57%, 73% respectively. Average ESP inlet mercury concentration
        was approx. 17 ug/dncm of which 85% was elemental. The carbon
        injection did not deteriorate ESP performance. However, the ESP
        is relatively large (468 SCA) and additional testing needs to be
        conducted on units with smaller ESPs. There was no improvement
        in mercury capture using the spray cooling system.

    -   Brayton Point: The PAC injection was located between the first
        and second cold-side ESPs. Average mercury concentration at the
        inlet to the first ESP was approx. 6 ug/dncm of which 85% was
        particulate-bound. During baseline testing the average mercury
        removal ranged from 30 to 90% across both ESPs and 0 to 10%
        across the second ESP. During the parametric testing of Norit's
        Darco FGD activated carbon at feed rates of 3, 7, 10, 15, and 20
        lb./MMacf the mercury capture averaged approx. 25%, 40%, 70%,
        75%, and 90% respectively across the second ESP. The carbon
        injection did not deteriorate ESP performance. However, the
        second ESP is relatively large (400 SCA) and additional testing
        needs to be conducted on units with smaller ESPs.

    -   Salem Harbor: Average mercury concentration at the inlet to the
        ESP was approx. 10 ug/dncm of which 95% was particulate-bound.
        During baseline testing without PAC injection, average mercury
        capture was approximately 90%. The high baseline mercury removal
        is attributed to high levels of unburned carbon (LOI was 25 to
        30%) and low flue gas temperature (approx. 270°F). Baseline
        mercury removal decreased from approx. 90% to 20% while
        increasing flue gas temperature from 270 to 350°F. The NOx SNCR
        system had no effect on mercury capture.

-   **[Contacts]{.underline}** For further information on this project,
    contact NETL Project Manager, Scott Renninger, or visit the NETL
    website at
    <http://www.netl.doe.gov/coalpower/environment/index.html>

-   **[Publications]{.underline}**

    -   Bustard, C. Jean; Durham, Michael; Lindsey, Charles; Starns,
        Travis; Baldrey, Ken; Martin, Cameron; Schlager, Richard;
        Sjostrom, Sharon; Slye, Rick; Monroe, Larry; Miller, Richard;
        Chang, Ramsey Full-Scale Evaluation of Mercury Control with
        Sorbent Injection and COHPAC at Alabama Power E.C. Gaston.
        Presented at the A&WMA Specialty Conference on Mercury
        Emissions: Fate, Effects, and Control and the US EPA/DOE/EPRI
        Combined Power Plant Air Pollutant Control Symposium: Mega
        Symposium, Chicago, IL, August 2001.

    -   Bustard, Jean; Durham, Mike; Starns, Travis; Lindsey, Charles;
        Martin, Cameron; Schlager, Richard; Baldrey, Ken Full-Scale
        Evaluation of Sorbent Injection for Mercury Control on
        Coal-Fired Power Plants. In *Proceedings of Air Quality III:
        Mercury, Trace Elements, and Particulate Matter Conference*;
        Arlington, VA, September 9-12, 2002.

    -   Bustard, C. Jean, et. al.; Results of Activated Carbon Injection
        Upstream of Electrostatic Precipitators for Mercury Control.
        Presented at the A&WMA/US EPA/DOE/EPRI Combined Power Plant Air
        Pollutant Control Mega Symposium, Washington, DC, May 19-22,
        2003.

    -   Bustard, C. Jean, et. al.; Results of Activated Carbon Injection
        for Mercury Control Upstream of a COHPAC Fabric Filter.
        Presented at the A&WMA/US EPA/DOE/EPRI Combined Power Plant Air
        Pollutant Control Mega Symposium, Washington, DC, May 19-22,
        2003.

> **[\
> ]{.underline}**

[Return to Project Summary Table](#ADA_table)

***DOE/NETL Environmental & Water Resources***

***Mercury Control Technology Project Fact Sheet***

**[B&W Full-Scale Testing of Enhanced Mercury Control in Wet
FGD]{.underline}**

(DE-FC26-00NT41006)

-   **[Objective]{.underline}** Conduct full-scale demonstration testing
    of a proprietary liquid reagent developed by Babcock & Wilcox and
    McDermott Technology, Inc. (B&W/MTI) to enhance the capture of
    mercury in coal-fired power plants equipped with wet flue gas
    desulfurization (FGD) systems. Previous pilot plant testing with the
    reagent resulted in an increase in mercury capture across the FGD
    system from a baseline of 71% to approximately 85%. The full-scale
    demonstration testing will provide design and performance
    information which can be used for future full-scale commercial
    applications of the technology.

-   **[Sponsors]{.underline}** The project is funded by NETL, the Ohio
    Coal Development Office, and Babcock & Wilcox. Host sites and
    associated support is provided by Michigan South Central Power
    Agency (MSCPA) and Cinergy.

-   **[Background]{.underline}** The mercury in coal-fired power plant
    combustion flue gas exists primarily as either elemental or oxidized
    mercury species. Previous testing has shown that although elemental
    mercury is not readily captured, oxidized mercury can be effectively
    captured in coal-fired power plants equipped with wet FGD systems.
    However, there is also evidence that a portion of the oxidized
    mercury is reduced back to elemental mercury within the wet FGD
    system and discharged out the stack. Therefore, a method to prevent
    the reduction of oxidized mercury back to elemental mercury would
    enhance the overall mercury capture across the wet FGD system.
    Previous B&W/MTI pilot plant testing evaluated a proprietary reagent
    that, when added to the wet FGD system scrubbing liquor, was able to
    prevent the reduction of oxidized mercury. This full-scale
    demonstration project is necessary to evaluate the long term
    effectiveness of the reagent for cost-effective use in future wet
    FGD commercial applications.

-   **[Project Description]{.underline}** The full-scale demonstration
    testing is being conducted at two power plants, MSCPA's 60 MW
    Endicott Station in Litchfield, Michigan and Cinergy's 1300 MW
    Zimmer Station in Moscow, Ohio. Both plants burn Ohio high sulfur
    bituminous coal and use cold-side ESPs for particulate control. The
    Endicott Station utilizes a limestone wet FGD system with in-situ
    forced oxidation; while the Zimmer Station utilizes a magnesium
    enhanced lime wet FGD system with ex-situ forced oxidation. The
    reagent feed equipment consists of a tanker truck for storage and a
    skid-mounted feed system with two metering pumps and associated
    controls. The field demonstration at both power plants was to
    include short-term parametric tests followed by four months of
    long-term testing. (The actual testing at Zimmer was limited to only
    two weeks.)

-   **[Schedule]{.underline}** Project started September 2000 and was
    completed in September 2002. Testing at the Endicott Station was
    completed in October 2001. Testing at the Zimmer Station was
    completed in November 2001. A final report was issued in August
    2002.

-   **[Cost]{.underline}** The total budget cost for the project is
    approximately \$2.0 million. (DOE funding \$1,305,374)

-   **[Status]{.underline}** The testing is complete at both power
    stations. A final report was issued in August 2002.

-   **[Results To Date]{.underline}** Test results were mixed and
    indicate a need for further study and evaluation prior to
    commercialization of the process. The testing at Endicott was
    successful since there was no appreciable increase in elemental
    mercury across the wet FGD system during reagent usage and total
    mercury removal averaged 77% (including 95% removal of the inlet
    oxidized mercury) compared to a baseline removal of approximately
    60%. However, the testing at Zimmer was not successful since there
    continued to be an increase in elemental mercury across the wet FGD
    system during reagent usage and there was no significant effect on
    total mercury removal which averaged 52% (including 87% removal of
    the inlet oxidized mercury) compared to a baseline removal of
    approximately 45%. Possible explanations for the poor results at
    Zimmer include the much higher sulfite concentration and lower
    liquid-to-gas ratio in the magnesium enhanced lime wet FGD system
    which may impede the reagent performance.

-   **[Contacts]{.underline}** For further information on this project,
    contact NETL Project Manager, Scott Renninger or visit the NETL
    website at
    <http://www.netl.doe.gov/coalpower/environment/index.html>.

-   **[Publications]{.underline}**

    -   Nolan, Paul; et. al. Mercury Emissions Control in Wet FGD
        Systems. In *Proceedings of Air Quality III: Mercury, Trace
        Elements, and Particulate Matter Conference*; Arlington, VA,
        September 9-12, 2002.

[Return to Project Summary Table](#BW_table)

***DOE/NETL Environmental & Water Resources***

***Mercury Control Technology Project Fact Sheet***

**[Pilot Plant Study of Low Temperature Mercury Capture with an
ESP]{.underline}**

(DE-FC26-01NT41181)

-   **[Objective]{.underline}** Conduct pilot testing at a coal-fired
    power plant to evaluate the performance of lowering the combustion
    flue gas temperature in order to enhance overall mercury capture in
    plants equipped only with existing electrostatic precipitators
    (ESP). Based on previous laboratory testing 80 to 90% mercury
    removal was achieved at a temperature of 200 degrees F. The pilot
    testing will provide engineering design and performance information
    which can be used for future full-scale commercial applications of
    the technology.

-   **[Sponsors]{.underline}** The project is being funded by NETL,
    CONSOL Energy, and Allegheny Energy. Other participants are Alstom
    Power Inc., Environmental Elements Corp., and Carmeuse North
    America.

-   **[Background]{.underline}** Based on results of the EPA's 1999
    mercury data information collection request (ICR) for coal-fired
    power plants, it was found that existing ESP's are capable of
    capturing some portion of the mercury in the combustion flue gases.
    However, the mercury capture efficiency of ESP's varies widely from
    plant-to-plant and is likely not sufficient to meet future EPA
    regulatory control requirements. Previous research conducted by
    CONSOL Energy demonstrated that the fly ash particles in power plant
    combustion flue gas can absorb a significant portion of the mercury
    if the gas is cooled below typical exhaust temperatures, e.g., from
    300 to 200 degrees F. However, operating at reduced flue gas
    temperatures also results in the condensation of SO~3~ which can
    lead to serious equipment and duct corrosion problems downstream of
    the air preheater. In order to address the corrosion problem, CONSOL
    Energy has conducted research of an alkaline sorbent injection
    system to reduce the flue gas SO~3~ concentration by approximately
    80% to allow for plant operation at the lower flue gas temperatures.
    The pilot plant project is necessary to demonstrate the long term
    effectiveness of this control strategy.

-   **[Project Description]{.underline}** The pilot testing is being
    conducted at Allegheny Energy's 288 MW Mitchell Power Station, Unit
    No. 3, which burns a medium sulfur, eastern bituminous coal. The
    pilot plant consists of an air preheater to lower flue gas
    temperature, a water spray cooling system as an optional method to
    lower flue gas temperature, an ESP to collect the mercury along with
    the fly ash, and an alkaline sorbent (magnesium hydroxide) injection
    system to control sulfuric acid condensation. The pilot plant is
    supplied with approximately a 16,500 lb/hr flue gas slipstream taken
    upstream of the plant's air preheater. Mercury capture across the
    ESP will be measured with varying air preheater outlet flue gas
    temperatures between 220 to 320 degrees F.

-   **[Schedule]{.underline}** Project started August 2001 and is to be
    completed in September 2004. The pilot testing is scheduled to begin
    in January 2003 and will be completed in March 2004. A final report
    will be issued in September 2004.

-   **[Cost]{.underline}** The total budget cost for the project is
    approximately \$ 2.4 million. (DOE funding \$1,826,539)

-   **[Status]{.underline}** The pilot plant equipment is in operation
    and baseline testing is to begin in May 2003.

-   **[Results To Date]{.underline}** None available.

-   **[Contacts]{.underline}** For further information on this project,
    contact NETL Project Manager, [Lynn A.
    Brickett](mailto:lynn.brickett@netl.doe.gov) or visit the NETL
    website at
    <http://www.netl.doe.gov/coalpower/environment/index.html>.

-   **[Publications]{.underline}**

[Return to Project Summary Table](#CONSOL_lowtemp_table)

***DOE/NETL Environmental & Water Resources***

***Mercury Control Technology Project Fact Sheet***

**[Assessment of Low Cost Novel Mercury Sorbents]{.underline}**

(DE-FC26-01NT41180)

-   **[Objective]{.underline}** Conduct pilot testing at two coal-fired
    power plants to assess the mercury capture performance of novel
    sorbents which could be used as an alternative to commercially
    available activated carbons in order to enhance performance and
    reduce operating costs for carbon injection mercury control systems.

-   **[Sponsors]{.underline}** The project is being funded by NETL,
    EPRI, and Apogee Scientific. Other project participants include URS,
    Illinois State Geological Survey, ADA Environmental Solutions,
    Physical Sciences Inc., Wisconsin Electric Power, and Midwest
    Generation.

-   **[Background]{.underline}** Activated carbon injection systems are
    currently under development for the control of mercury emissions
    from coal-fired power plants. However, the commercially available
    activated carbons currently being used in full-scale field
    demonstrations of the control technology are relatively expensive.
    Therefore, the development of alternative lower cost sorbents could
    significantly reduce the cost of mercury control. This project is
    necessary to assess the mercury capture performance of several low
    cost novel mercury sorbents using an actual flue gas slipstream in a
    small-scale pilot plant equipped with an ESP and baghouse.

-   **[Project Description]{.underline}** The pilot testing is being
    conducted at two power plants, Wisconsin Electric Power's Valley
    Plant in Milwaukee, WI which uses a low sulfur bituminous coal and
    Midwest Generation's Powerton Generating Station in Pekin, IL which
    uses a Powder River Basin sub-bituminous coal. The sorbents being
    tested include activated carbon samples from coal, biomass, and
    tires; char sorbents made from coal; fly ash derived sorbents; and
    zeolite sorbents. Initially, bench-scale laboratory tests were
    conducted on 46 different sorbents using simulated bituminous coal
    flue gas and 29 sorbents using simulated PRB coal flue gas. Based on
    results from the bench-scale testing 17 sorbents for bituminous
    applications and 8 sorbents for PRB applications were selected for
    additional fixed-bed testing using actual flue gas slipstreams at
    the two plants. The fixed-bed testing at the plants led to the final
    selection of sorbents for testing in a small-scale (10 to 50 acfm)
    slipstream pilot plant equipped with a residence chamber to simulate
    an ESP and a baghouse to simulate a COHPAC configuration.

-   **[Schedule]{.underline}** Project started August 2001 and is to be
    completed in August 2003. The field pilot testing of the sorbents is
    scheduled for completion by February 2003. A final report is
    scheduled for completion by August 2003.

-   **[Cost]{.underline}** The total budget cost for the project is
    approximately \$0.8 million. (DOE funding \$550,654)

-   **[Status]{.underline}** Seven sorbents were selected for testing in
    the small-scale pilot at Powerton which was completed in July 2002.
    The small-scale pilot testing at the Valley Plant started in
    December 2002 and should be completed by February 2003.

-   **[Results To Date]{.underline}** The Powerton slipstream pilot
    testing included experimental sorbents produced from corn (CFA), oil
    soot (CS80), waste tires (TDAC), flyash (STI-B), a commercially
    available carbon made from lignite coal (HOK), and an
    iodine-impregnated sorbent (CB-IAC). Norit's Darco FGD activated
    carbon was also tested as a benchmark. Major results from the
    Powerton pilot testing are as follows:

    -   Initial screening tests were conducted at 1.5 lb/MMacf and 300°F
        using the COHPAC configuration. Similar mercury removal of
        approximately 80% was achieved by the FGD, CFA, CS80, and HOK
        sorbents. Mercury removal for the TDAC and STI-B were
        approximately 60% and 35% respectively. The CB-IAC mercury
        removal was 72% at a lower injection rate of 0.6 lb/MMacf. The
        CFA and HOK sorbents were selected for additional parametric
        testing in the COHPAC configuration based on their lower
        estimated delivered cost.

    -   The parametric and long-term COHPAC testing again showed similar
        performance of the CFA, HOK, and FGD sorbents. However, mercury
        removal was different for the two types of filter bag materials
        that were tested. At 2 lb/MMacf the three sorbents achieved
        approximately 90% mercury removal with the Teflon glass bag, but
        only 70 - 80% mercury removal with the Torcon bag. However, the
        difference in mercury removal may have been a result of the bag
        cleaning frequency used during the testing. Mercury removal was
        also similar for the three sorbents at both 300° and 350° F.

    -   Based on results of the COHPAC screening tests, the CFA and CS80
        were selected for testing in the residence chamber (ESP)
        configuration. The FGD and IAC sorbents were also included as
        benchmarks. The CFA, CS80, and FGD mercury removal was less than
        50% for injection rates between 2.5 and 15 lb/MMacf at both two
        and four second residence times. The IAC sorbent achieved
        approximately 60% mercury removal at four seconds and 45% at two
        seconds at 2.5 lb/MMacf.

    -   Preliminary cost estimates for the alternative sorbents indicate
        production costs could be approximately 50% less than
        commercially available activated carbons.

> The Valley Plant test results are not yet available.

-   **[Contacts]{.underline}** For further information on this project,
    contact NETL Project Manager, Bob Patton, or visit the NETL website
    at <http://www.netl.doe.gov/coalpower/environment/index.html>

-   **[Publications]{.underline}**

[Return to Project Summary Table](#Apogee_sorbents_table)

***DOE/NETL Environmental & Water Resources***

***Mercury Control Technology Project Fact Sheet***

**[Mercury Control with the Advanced Hybrid Particulate
Collector]{.underline}**

(DE-FC26-01NT41184)

-   **[Objective]{.underline}** Conduct bench-scale testing, small
    pilot-scale testing, and large pilot-scale field demonstration
    testing to evaluate the mercury control performance of sorbent
    injection used in conjunction with the Advanced Hybrid Particulate
    Collector (AHPC). The pilot-scale field demonstration testing will
    provide engineering design and performance information which can be
    used for future full-scale commercial applications of the
    technology.

-   **[Sponsors]{.underline}** The project is being funded by NETL and
    the University of North Dakota Energy and Environmental Research
    Center (EERC). Other participants are W.L. Gore & Associates and
    Otter Tail Power Company.

-   **[Background]{.underline}** NETL has previously supported the RD&D
    of the AHPC which is a combination electrostatic precipitator (ESP)
    and fabric filter baghouse (FF) system designed to optimize fine
    particulate collection. While sorbent injection used in conjunction
    with conventional ESPs and FFs is being demonstrated to be effective
    for mercury capture, the AHPC may be capable of equivalent or better
    performance at lower sorbent feed rates which is to be demonstrated
    under this project.

-   **[Project Description]{.underline}** Bench-scale and small
    pilot-scale testing is being conducted at EERC. Field demonstration
    pilot plant testing is being conducted at Otter Tail Power Company's
    450 MW Big Stone Plant located in Big Stone City, South Dakota,
    which burns Powder River Basin sub-bituminous coal. The bench-scale
    testing is being conducted to evaluate mercury capture effectiveness
    of activated carbon sorbents under varying SO~2~ and NOx flue gas
    concentrations using both simulated and real flue gas. The small
    pilot-scale testing will use the 200 acfm EERC particulate test
    combustor (PTC) and is being conducted to compare the mercury
    capture effectiveness of a pulse-jet baghouse and the AHPC both with
    and without sorbent addition for both an eastern bituminous and
    western sub-bituminous coal. The field demonstration pilot plant
    testing will use the 9,000 acfm (2.5 MW) AHPC pilot plant previously
    installed at the Big Stone Plant to demonstrate the AHPC technology
    for particulate control. A pilot-scale sorbent injection system is
    being added to the AHPC pilot plant for the mercury control testing.
    NORIT Darco FGD activated carbon was used for both the 200 acfm and
    2.5 MW pilot-scale testing.

-   **[Schedule]{.underline}** Project started June 2001 and is to be
    completed in December 2004. The long-term field demonstration pilot
    plant testing is scheduled to be completed by the spring of 2003. A
    final report is expected to be available by September 2003.

-   **[Cost]{.underline}** The total budget cost for the project is
    approximately \$1.5 million. (DOE funding \$2,641,120)

-   **[Status]{.underline}** The initial short-term field demonstration
    baseline pilot plant testing was conducted in November 2001. The
    bench-scale and small pilot-scale testing were completed in March
    and June 2002 respectively. The long-term field demonstration
    pilot-plant testing is scheduled to be completed by the spring of
    2003.

-   **[Results To Date]{.underline}**

-   Results from the small pilot-scale testing burning a Belle Ayr PRB
    coal indicated approximately 70% of the mercury was elemental and
    there was very little baseline mercury capture from both the AHPC
    and pulse-jet baghouse. Mercury removal with the AHPC ranged from
    50% to 71% at a carbon-to-mercury mass ratio of 3000:1 and from 65%
    to 87% at a mass ratio of 6000:1.

-   Results from the November 2001 short-term AHPC 2.5 MW pilot-plant
    test at Big Stone indicated 91 to 97% total mercury collection
    efficiency with a sorbent feed rate of 1.5 lb/million acf compared
    to a baseline (no sorbent) mercury collection efficiency of 49%. The
    relatively high mercury removal rates may have occurred because the
    average inlet mercury speciation during the testing was 55.4%
    particulate, 38.1% oxidized, and only 6.4% elemental. This is not
    considered typical for PRB coals, which normally have much higher
    levels of elemental mercury. Subsequent analysis showed that the
    high proportion of particulate and oxidized mercury may have been
    related to unexpectedly high levels of chlorine in the flue gas,
    which may have resulted from co-combustion of tire-derived fuel
    (TDF) in the Big Stone boiler during the November 2001 test period.

-   A second AHPC 2.5 MW pilot-plant test was conducted at Big Stone in
    August 2002 using a Belle Ayr PRB coal. Mercury speciation was 17%
    particulate, 32% oxidized, and 51% elemental. Baseline mercury
    removal ranged from 0% to 10%. Mercury removal was 63% during
    activated carbon injection at 1.5 lb/MMacf and without any TDF
    co-firing. There was no adverse effect on AHPC particulate
    collection performance during the activated carbon injection
    testing.

-   A third AHPC 2.5 MW pilot-plant test was conducted at Big Stone in
    November 2002. Mercury removal ranged from 65% to over 90% during
    activated carbon injection at 1.5 lb/MMacf and without any TDF
    co-firing. A possible reason for the improved mercury removal in
    November compared to the August 2002 test is lower flue gas
    temperature of 250° F compared to 270° - 290°F. Supplemental
    injection of HCl had little or no effect on mercury removal.

-   A small AHPC 200 acfm pilot-scale test was conducted in late 2002
    using a Springfield high-sulfur bituminous coal. The NORIT Darco FGD
    activated carbon was ineffective with average mercury removal at
    less than 15% for various combinations of flue gas temperature
    (275° - 320°F) and injection rates. A possible reason for the poor
    mercury removal was the relatively high level of SO~3~ (over 30 ppm)
    concentration in the flue gas.

-   **[Contacts]{.underline}** For further information on this project,
    contact NETL Project Manager, Bill Aljoe or visit the NETL website
    at <http://www.netl.doe.gov/coalpower/environment/index.html>

-   **[Publications]{.underline}**

    -   Miller, Stanley; Zhuang, Ye; Rinschler, Craig; Gebert, Rich;
        Davis, Dwight; Swanson, William Mercury Control with the
        Advanced Hybrid. In *Proceedings of Air Quality III: Mercury,
        Trace Elements, and Particulate Matter Conference*; Arlington,
        VA, September 9-12, 2002.

[Return to Project Summary Table](#EERC_AHPC_table)

***DOE/NETL Environmental & Water Resources***

***Mercury Control Technology Project Fact Sheet***

**[Mercury Removal in a Non-Thermal, Plasma-Based]{.underline}**

**[Multi-Pollutant Control Technology for Utility Boilers]{.underline}**

(DE-FC26-01NT41182)

-   **[Objective]{.underline}** Conduct pilot-scale field demonstration
    testing to optimize the mercury control performance of Powerspan's
    Electro Catalytic Oxidation (ECO) multi-pollutant control technology
    process while maintaining high removal levels of SO~2~, NOx, and
    fine particulate matter. The pilot-scale testing will provide
    engineering design and performance information which can be used for
    future full-scale commercial applications of the technology.

-   **[Sponsors]{.underline}** The project is being funded by NETL and
    Powerspan Corp. Other participants include FirstEnergy Corporation.

-   **[Background]{.underline}** Powerspan has developed a non-thermal,
    plasma -based multi-pollutant control technology known as the
    Electro Catalytic Oxidation (ECO) process that was designed for the
    simultaneous removal of SO~2~, NOx, and fine particulate emissions
    from the combustion flue gas of coal-fired boilers. Based on
    previous pilot-plant testing it was determined that the ECO process
    has the potential for significant mercury removal. The ECO process
    includes a dielectric barrier discharge (DBD) which converts the
    elemental mercury to mercuric oxide which can be efficiently
    captured along with any previously oxidized mercury in a downstream
    ammonia reagent-based wet FGD absorber and wet ESP.

-   **[Project Description]{.underline}** The pilot-scale field
    demonstration testing is being conducted at First Energy's R.E.
    Burger Plant located in Shadyside, Ohio, which burns eastern
    bituminous coal. The testing will use a 3,000 scfm flue gas
    slip-stream pilot-scale ECO system previously installed for a field
    demonstration of the process. (Note: A large full-scale 50 MW
    commercial ECO system is under construction at the R.E. Burger Plant
    and is expected to be ready for operation during the 2^nd^ quarter
    2003.) The ECO pilot plant is being equipped with a PS Analytical
    mercury CEMs system to provide continuous mercury speciation
    measurements across the various ECO process components during the
    testing. In addition, an activated carbon filtration system is being
    developed and installed for removal of the captured mercury from the
    wet FGD discharge liquid product stream prior to crystallization of
    the ammonium sulfate and nitrate byproducts.

-   **[Schedule]{.underline}** Project started September 2001 and is to
    be completed in March 2004. The pilot-scale field demonstration
    testing is scheduled to be complete by September 2003 and a final
    report will be issued by March 2004.

-   **[Cost]{.underline}** The total budget cost for the project is
    approximately \$2.8 million. (DOE funding \$2,248,002)

-   **[Status]{.underline}** Initial baseline mercury speciation
    measurements were obtained across the pilot plant dry ESP during the
    3^rd^ quarter 2002. Bench-scale testing of the activated carbon
    filtration system has also been initiated.

-   **[Results To Date]{.underline}** Preliminary Ontario Hydro method
    test measurements in May 2002 resulted in an average mercury removal
    of 88% across the ECO pilot plant. While particulate and oxidized
    mercury removal exceeded 95%, there was some apparent conversion of
    oxidized mercury to elemental mercury which reduced the overall
    removal. Normal inlet flue gas elemental mercury concentration is
    extremely low at the Burger Plant and artificial injection of
    elemental mercury into the pilot plant is being tested to
    demonstrate ECO capability to capture elemental mercury. Mercury
    captured in the ECO ammonia scrubber liquid is removed using a
    sulfur-impregnated activated carbon filter (Mersorb). Mercury levels
    in the scrubber liquid have been reduced from 200 ppb to less than
    the limit of detection (approx. 20 ppb).

-   **[Contacts]{.underline}** For further information on this project,
    contact NETL Project Manager, Scott Renninger, or visit the NETL
    website at
    <http://www.netl.doe.gov/coalpower/environment/index.html>

-   **[Publications]{.underline}**

    -   McLarnon, Christopher Mercury Removal in a Multi-Pollutant
        Control Technology for Utility Boilers. In *Proceedings of Air
        Quality III: Mercury, Trace Elements, and Particulate Matter
        Conference*; Arlington, VA, September 9-12, 2002.

    -   McLarnon, C. and Steen, D.; Combined SO~2~, NOx, PM, and Hg
        Removal from Coal-Fired Boilers. Presented at the A&WMA/US
        EPA/DOE/EPRI Combined Power Plant Air Pollutant Control Mega
        Symposium, Washington, DC, May 19-22, 2003.

[Return to Project Summary Table](#Powerspan_ECO_table)

***DOE/NETL Environmental & Water Resources***

***Mercury Control Technology Project Fact Sheet***

**[Testing of Mercury Control with Calcium-Based Sorbents and Oxidizing
Agents]{.underline}**

(DE-FC26-01NT41183)

-   **[Objective]{.underline}** Conduct bench-scale and pilot-scale
    testing to assess the mercury capture performance of calcium-based
    sorbents and oxidizing agents which could be used as an alternative
    to commercially available activated carbons in order to enhance
    performance and reduce operating costs for carbon injection mercury
    control systems used at coal-fired power plants.

-   **[Sponsors]{.underline}** This project is being funded by NETL and
    the Southern Research Institute (SRI). Other project participants
    include ARCADIS G&M, Inc.

-   **[Background]{.underline}** Activated carbon injection systems are
    currently under development for the control of mercury emissions
    from coal-fired power plants. However, the commercially available
    activated carbons currently being used in full-scale field
    demonstrations of the control technology are relatively expensive.
    Therefore, the development of alternative lower cost sorbents could
    significantly reduce the cost of mercury control. Working with the
    EPA, ARCADIS has developed two proprietary calcium-based sorbents
    which could provide for the simultaneous removal of both mercury and
    sulfur dioxide from coal-fired power plants. The two sorbents
    consist of a hydrated lime, Ca(OH)~2~, with an oxidant and a
    silica-modified calcium, CaSiO~3~, with an oxidant. The oxidant is
    intended to oxidize the elemental mercury in order to enhance
    overall mercury capture by the sorbent. This project is necessary to
    assess the mercury capture performance of these and other
    calcium-based sorbents using flue gas from a pilot-scale coal
    combustor. Other calcium-based sorbents such as lime will be used
    with alternative oxidants such as injected chlorine compounds,
    sodium tetra-sulfide, or high iron oxide fly ash from the
    bituminuous coal. These oxidants will be tested with a lime sorbent
    on a subbituminous Powder River Basin coal that characteristically
    has a high fraction of elemental mercury.

-   **[Project Description]{.underline}** SRI is testing the
    calcium-based sorbents at its Combustion Research Facility located
    in Birmingham, AL using a 1 MW (1150 SCFM) pilot plant. The
    calcium-based sorbents are being tested on a variety of coal types
    and flue gas conditions. The pilot plant sorbent injection system
    includes a downstream water injection cooling system followed by a
    fabric filter baghouse for particulate and mercury capture. A PS
    Analytical mercury CEMs system is being used for speciated mercury
    measurements across the pilot plant during the sorbent injection
    testing.

-   **[Schedule]{.underline}** Project started September 2001 and is to
    be completed in September 2004. The test program is to consist of
    numerous pilot plant runs over a three-year project period.

-   **[Cost]{.underline}** The total budget cost for the project is
    approximately \$1.4 million. (DOE funding \$1,109,719)

-   **[Status]{.underline}** Initial pilot-plant testing of the two
    proprietary calcium-based sorbents and an ordinary hydrated lime
    sorbent was completed in the spring 2002.

-   **[Results To Date]{.underline}**

    -   The initial pilot-plant testing of the two proprietary
        calcium-based sorbents with an oxidant additive and bituminous
        coal showed both to be ineffective in enhancing the oxidation
        and capture of elemental mercury and achieved overall mercury
        removal of only 25 to 50%. Follow-up testing with an ordinary
        hydrated lime sorbent without the oxidant was able to remove 80
        to 90% of the mercury which occurred primarily across the
        sorbent dust cake collecting on the baghouse filter bags.
        Approximately 30 to 35% mercury capture occurred "in-flight"
        prior to the baghouse.

    -   SRI and PS Analytical developed a "spike and recovery" system to
        reduce mercury S-CEM measurement uncertainty. A known
        concentration mercury "spike" is introduced in the sampling
        probe in order to increase the concentration of mercury in the
        sampled flue gas.

    -   Pilot-scale testing with a kaolinite (Al~2~O~3~.2SiO~2~.H~2~O)
        adsorbent and a Choctaw bituminous coal was ineffective for
        mercury capture at injection temperatures that ranged from 1100°
        to 2100°F.

    -   SRI conducted pilot-scale testing of chlorine gas (Cl~2~)
        injection in order to evaluate the ability of HCl to promote
        mercury oxidation and adsorption with PRB coal ash. Chlorine
        injection through the burner was effective in increasing the
        oxidized mercury from less than 20% to over 50% and increasing
        mercury adsorption on the PRB coal ash from less than 5% to over
        30%. However, chlorine injection upstream of the air heater was
        ineffective.

    -   SRI conducted pilot-scale testing to condition PRB coal with a
        high-iron, low-chlorine bituminous coal. As a result, PRB coal
        ash composition was found to be more important than flue gas
        chlorine content relative to mercury oxidation and capture. With
        PRB coal only, there was less than 15% oxidized mercury at the
        baghouse inlet. However, a coal blend with 10% bituminous and
        90% PRB coal resulted in greater than 50% oxidized mercury at
        the baghouse inlet.

    -   SRI also conducted tests to condition the PRB coal ash with
        injection of high-iron bituminous coal ash and hydrated lime at
        the baghouse inlet. The rate of ash/lime injection was
        approximately equivalent to the PRB ash loading. Three ash/lime
        injection ratios were tested: 100% ash; 50% ash/ 50% lime; and
        20% ash/ 80% lime. The mercury oxidation across the baghouse
        increased from a baseline of approximately 60% to 80% with 100%
        high-iron bituminous ash injection. The increase in mercury
        oxidation was less with the ash/lime blends.

    -   Increasing the baghouse inlet flue gas temperature from 260° to
        300°F increased oxidized mercury while burning 100% PRB coal.
        The oxidized mercury increased less than 10 percentage points at
        the baghouse inlet, but increased approximately 30 percentage
        points at the baghouse outlet. However, this temperature effect
        was not significant with the bituminous/PRB coal blend.

-   **[Contacts]{.underline}** For further information on this project,
    contact NETL Project Manager, Barbara Carney, or visit the NETL
    website at
    <http://www.netl.doe.gov/coalpower/environment/index.html>

-   **[Publications]{.underline}**

    -   Gale, Thomas K. et al.; Mercury Speciation as a Function of Flue
        Gas Chlorine Content and Composition in a 1 MW Semi-Industrial
        Scale Coal-Fired Facility. Presented at the A&WMA/US
        EPA/DOE/EPRI Combined Power Plant Air Pollutant Control Mega
        Symposium, Washington, DC, May 19-22, 2003.

[Return to Project Summary Table](#SRI_sorbents_table)

***DOE/NETL Environmental & Water Resources***

***Mercury Control Technology Project Fact Sheet***

**[Pilot Testing of Mercury Oxidation Catalysts]{.underline}**

(DE-FC26-01NT41185)

-   **[Objective]{.underline}** Conduct pilot testing at two coal-fired
    power plants to evaluate the performance of several catalyst
    materials that would be used to promote the oxidation of elemental
    mercury in the flue gas in order to enhance overall mercury capture
    in plants equipped with existing wet flue gas desulfurization (FGD)
    systems. Based on laboratory testing a minimum 90% mercury oxidation
    rate is expected from the pilot testing. The pilot testing will
    provide engineering design and performance information which can be
    used for future full-scale commercial applications of the
    technology.

-   **[Sponsors]{.underline}** The project is being funded by NETL,
    EPRI, Great River Energy (GRE), City Public Service (CPS) of San
    Antonio, and the North Dakota Industrial Council. URS Corporation is
    the prime contractor.

-   **[Background]{.underline}** The mercury in coal-fired power plant
    combustion flue gas exists primarily as either elemental or oxidized
    mercury species. The degree of mercury speciation can vary
    significantly from plant to plant, but in general plants burning
    sub-bituminous or lignite coal have a higher percentage of elemental
    mercury compared to bituminous coal. Previous testing has shown that
    although elemental mercury is not readily captured, oxidized mercury
    can be effectively captured in coal-fired power plants equipped with
    wet FGD systems. Therefore, a method to convert the elemental
    mercury to oxidized mercury in the flue gas would enhance the
    overall mercury capture. A previous NETL/EPRI project evaluated
    several catalyst materials in small, fixed sand-bed reactors that
    were effective in the oxidation of elemental mercury. This pilot
    project is necessary to demonstrate the long term effectiveness of
    these catalysts on honeycomb substrates that could be used in
    full-scale commercial applications.

-   **[Project Description]{.underline}** The pilot testing is being
    conducted at two power plants, the GRE Coal Creek Station which uses
    a North Dakota lignite fuel and the CPS J.K. Spruce Plant which uses
    a Powder River Basin (PRB) sub-bituminous fuel. The four catalysts
    being tested are: 1) Pd #1, a commercial palladium catalyst; 2) SCR,
    a Siemens commercial NOx catalyst using titanium-vanadium; 3) Carbon
    #6, an activated tire-derived carbon; and 4) SBA #5, an active fly
    ash. Each of the four catalysts, are contained on honeycomb design
    alumina substrates and mounted in separate 40" cube test chambers
    that are supplied with approximately a 2,000 acfm flue gas
    slipstream taken downstream of the plant's particulate control
    device.

-   **[Schedule]{.underline}** Project started August 2001 and is to be
    completed in August 2004. The GRE Coal Creek Station pilot testing
    was scheduled to begin in October 2002 and the CPS J.K. Spruce Plant
    was scheduled to begin in March 2003. The testing at each plant is
    scheduled for 14 months. A final report will be issued by August
    2004.

-   **[Cost]{.underline}** The total budget cost for the project is
    approximately \$1.2 million. (DOE funding \$897,616)

-   **[Status]{.underline}** The pilot unit at the Coal Creek Station
    began initial operation in October 2002 and should be completed by
    December 2003. Testing at J.K. Spruce Plant is scheduled to begin in
    the third quarter 2003.

-   **[Results To Date]{.underline}**

> Coal Creek Station:

-   Pilot testing for the Pd #1 and SCR catalysts began in October 2002.
    Oxidation of elemental mercury across Pd #1 dropped from 93% to 53%
    after 62 days in service. Oxidation of elemental mercury across the
    SCR catalyst dropped from 67% to 28% after 62 days in service.
    Subsequent inspection of the two catalysts indicated that a buildup
    of fly ash in the pilot test chamber likely caused the drop in
    oxidation rather than a loss of catalyst activity since mercury
    oxidation was restored after cleaning in January 2003.

-   A sonic horn is being tested to prevent the buildup of fly ash in
    the Pd #1 chamber and will be installed on the remaining chambers if
    effective.

-   Testing of the SBA #5 catalyst began in December 2002 and oxidation
    of elemental mercury was 75% when first measured in late January
    2003.

-   The Carbon #6 catalyst testing is being postponed until the fly ash
    buildup problem is corrected.

-   There was some concern that the catalysts might also lead to
    oxidation of SO~2~ and NO which could produce undesirable
    balance-of-plant effects. However, there is no apparent oxidation of
    SO~2~ to SO~3~ and approximately 7% oxidation of NO to NO~2~.

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-   **[Contacts]{.underline}** For further information on this project,
    contact NETL Project Manager, [Bruce
    Lani](mailto:bruce.lani@netl.doe.gov) or visit the NETL website at
    <http://www.netl.doe.gov/coalpower/environment/index.html>.

-   **[Publications]{.underline}**

    -   Blythe, Gary; Richardson, Carl; Rhudy, Richard Pilot Evaluation
        of the Catalytic Oxidation of Mercury for Enhanced Removal in
        Wet FGD Systems. In *Proceedings of Air Quality III: Mercury,
        Trace Elements, and Particulate Matter Conference*; Arlington,
        VA, September 9-12, 2002.

    -   Blythe, Gary et. al.; Pilot Testing of Oxidation Catalysts for
        Enhanced Mercury Control by Wet FGD. Presented at the A&WMA/US
        EPA/DOE/EPRI Combined Power Plant Air Pollutant Control Mega
        Symposium, Washington, DC, May 19-22, 2003.

[Return to Project Summary Table](#URS_catalyst_table)

***DOE/NETL Environmental & Water Resources***

***Mercury Control Technology Project Fact Sheet***

**[Evaluation of Mercury Speciation at Power Plants]{.underline}**

**[Using SCR and SNCR NOx Control Technologies]{.underline}**

(DE-FC26-98FT40321-36)

-   **[Objective]{.underline}** Conduct field testing at numerous
    coal-fired power plants equipped with selective catalytic reduction
    (SCR) or selective non-catalytic reduction (SNCR) NOx control
    technologies to determine their effect on the speciation of mercury
    in the combustion flue gas and resultant enhancement of mercury
    emissions capture in downstream pollution control equipment.

-   **[Sponsors]{.underline}** The project is being funded by NETL, the
    University of North Dakota Energy and Environmental Research Center
    (EERC), the Electric Power Research Institute (EPRI), and the
    Environmental Protection Agency (EPA). Other participants include
    numerous electric utility companies that provided host sites for the
    testing.

-   **[Background]{.underline}** The mercury in coal-fired power plant
    combustion flue gas exists as either elemental, oxidized, or
    particulate-bound species, and the degree of mercury speciation can
    vary significantly from plant to plant depending on coal type and
    combustion conditions. Although elemental mercury is not readily
    captured, oxidized and particulate mercury can be effectively
    captured in a plant's conventional pollution control equipment such
    as an ESP, baghouse, or FGD system. Previous pilot-scale testing
    indicated that the catalyst and/or ammonia reagent associated with
    SCR and SNCR NOx control technologies might further convert some of
    the elemental mercury to oxidized mercury in the flue gas and
    therefore enhance overall mercury capture. This field testing
    project is necessary to demonstrate the effectiveness of SCR and
    SNCR NOx control technologies to promote the oxidation of elemental
    mercury in full-scale commercial applications.

-   **[Project Description]{.underline}** The initial 2001 field testing
    was conducted at six coal-fired power plants. Four of the plants are
    equipped with SCR NOx controls, one plant uses SNCR NOx control, and
    one plant uses ammonia and sulfur trioxide for ash conditioning to
    improve particulate control. Field testing was also conducted in
    2002 at two of the 2001 SCR equipped plants and two additional
    plants with SCRs. Additional plants may be selected for testing
    in 2003. The field testing included the use of both the manual
    Ontario Hydro method and semi-continuous emission monitors (SCEM's)
    to measure the speciated mercury concentrations at the inlet and
    outlet of the SCRs to determine changes in the level of oxidized
    mercury.

-   **[Schedule]{.underline}** Project started April 2001 and is to be
    completed in October 2003. Field testing was scheduled for 2001,
    2002, and 2003 at various plants. A final report for the 2001
    testing was issued in October 2002.

-   **[Cost]{.underline}** The total budget cost for the project is
    approximately \$1.25 million. (DOE funding \$445,000)

-   **[Status]{.underline}** The 2002 field testing has been completed
    and a draft final report is under review. Two additional plants are
    being tested in 2003.

-   **[Results]{.underline}** The 2001 field-testing was conducted at
    six coal-fired power plants. Four of the plants are equipped with
    SCR controls, one plant uses SNCR control, and one plant uses
    ammonia and sulfur trioxide for ash conditioning to improve
    particulate control. Field-testing was conducted in 2002 at two of
    the 2001 SCR equipped plants and two additional plants with SCRs.
    Overall test results are as follows:

    -   SNCR and NH3/SO3 flue gas conditioning did not affect mercury
        oxidation.

    -   For the bituminous plants, the increase in oxidized mercury
        across the SCR varied significantly from 11 to 70 percentage
        points. The oxidized mercury at the downstream pollution control
        device (PCD) inlet, increased from -1 to 37 percentage points
        with an average of 17%. However, for the two sites with minimal
        SCR oxidation, the non-elemental mercury was greater than 90%
        both with and without the SCR.

    -   SCR catalyst did not significantly promote the oxidation of
        mercury for the one PRB test site. The oxidized mercury
        increased 20 percentage points across the SCR, but was unchanged
        at the PCD inlet.

    -   SCR catalysts promote mercury capture in wet FGD systems and
        possibly reduce the re-emission of elemental mercury. For the
        three plants with SCR and wet FGD, mercury removal was 84 - 92%
        (average 89%) with SCR operation and 43 - 51% (average 48%)
        without SCR operation.

    -   SCR size, as measured by space velocity, appeared to have a
        minimal affect on mercury oxidation across the SCR. There was no
        significant difference in non-elemental mercury at the SCR
        outlet or PCD inlet for the five bituminous plants.

    -   Based on results from the two plants tested in 2001 and 2002, it
        is uncertain whether SCR catalyst aging affects mercury
        oxidation. The increase in oxidized mercury across the SCR at
        site S2 decreased from 43 percentage points in 2001 to 33
        percentage points in 2002. However, there was no change in
        oxidized mercury at the PCD inlet which remained approx. 97%.
        The increase in oxidized mercury across the SCR at site S4
        decreased from 70 percentage points in 2001 to 29 percentage
        points in 2002. Again however, there was no change in oxidized
        mercury at the PCD inlet which was 93% in 2001 and 95% in 2002.

-   **[Contacts]{.underline}** For further information on this project,
    contact NETL Project Manager, Lynn Brickett, or visit the NETL
    website at
    <http://www.netl.doe.gov/coalpower/environment/index.html>

-   **[Publications]{.underline}**

    -   EPRI. *Power Plant Evaluation of the Effect of Selective
        Catalytic Reduction in Mercury*; EPRI Report No. 1005400;
        December 2002.

    -   Results from 2001 field testing were published in February 2003
        edition of AWMA's *EM Magazine*.

    -   L. Brickett, et. al.; Impact of SCR on Mercury Speciation for
        Coal-Fired Boilers. Presented at the A&WMA/US EPA/DOE/EPRI
        Combined Power Plant Air Pollutant Control Mega Symposium,
        Washington, DC, May 19-22, 2003.

[**Return to Project Summary Table**](#EERC_SCR_speciation_table)

***DOE/NETL Environmental & Water Resources***

***Mercury Control Technology Project Fact Sheet***

**[Evaluation of Mercury Control Technologies for Utilities Burning
Lignite Coal]{.underline}**

(DE-FC26-98FT40321-45)

-   **[Objective]{.underline}** Conduct a three-year, two-phase project
    to develop and test sorbent injection mercury control technologies
    for utilities that burn lignite coal. The first phase of the
    project, scheduled for 2002-2003, is to conduct bench-scale and
    pilot-scale evaluation for screening of potential sorbents. The
    second phase of the project, scheduled for 2003-2004, is to conduct
    full-scale field tests of the selected sorbents at a lignite-fired
    power plant.

-   **[Sponsors]{.underline}** The project is being funded by NETL and
    UNDEERC. Other participants include EPRI and several electric
    utilities that operate lignite-fired plants.

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-   **[Background]{.underline}** The combustion flue gas of
    lignite-fired power plants primarily contains elemental mercury and
    therefore results in minimal mercury capture across the existing air
    pollution control equipment. Therefore, potential sorbents must be
    evaluated to develop a cost-effective sorbent injection control
    technology applicable to lignite-fired plants.

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-   **[Project Description]{.underline}** The bench- and pilot-scale
    testing is being conducted at UNDEERC. Initial bench-scale
    laboratory tests were conducted on 11 different sorbents using a
    fixed-bed reactor and simulated lignite coal combustion flue gas. In
    addition to commercially available activated carbons, several
    high-sodium lignite coals were used to produce activated carbons. An
    ARCADIS calcium silicate sorbent was also included in the
    bench-scale testing. The pilot-scale testing uses the 200 acfm
    UNDEERC particulate test combustor and is being conducted to compare
    the sorbent mercury capture effectiveness of an ESP, fabric filter,
    and the UNDEERC advanced hybrid particulate collector (AHPC). The
    pilot-scale testing is being conducted using two different lignite
    coals (Luscar and Freedom).

-   **[Schedule]{.underline}** Project started February 2002 and is to
    be completed by \_\_\_\_\_\_\_\_\_\_.

-   **[Cost]{.underline}** The total budget cost for the project is
    approximately \$\_\_ million. (DOE funding \$\_\_\_\_\_)

-   **[Status]{.underline}** The Phase I bench- and pilot-scale testing
    was completed in November 2002. A Phase I draft final report has
    been submitted for review.

-   **[Results To Date]{.underline}** Bench-scale tests results
    indicated that the inactivated lignite-based carbon sorbents and
    calcium silicate were not effective. The lignite-based carbon
    sorbents activated at 800^o^C performed significantly better than
    the same carbon sorbents activated at 750^o^C. The bench-scale
    testing also demonstrated the importance of hydrogen chloride in the
    flue gas, which apparently conditions the sorbents. The DARCO FGD
    and 800^o^C activated Luscar char-derived sorbents were selected for
    further pilot-scale testing. Results from the pilot-scale testing
    are:

-   The Poplar River coal had a higher mercury concentration than the
    Freedom coal, but both coals resulted in similar speciation with 85%
    elemental and 15% oxidized mercury.

-   Lignite coal requires a higher sorbent feed rate for similar mercury
    removal compared to full-scale data for bituminous coal. To achieve
    70% mercury removal, the best Luscar sorbent injection rates were
    17.1, 7.8, and 2.92 lb/MMacf for the ESP, FF, and combined ESP-FF
    configurations respectively.

-   Mercury removal was approximately 10 -15 percentage points higher
    for the Freedom coal compared to the Poplar River coal for the
    ESP-only configuration.

-   Mercury removal was approx. 10 - 15 percentage points lower for both
    the Freedom and Poplar River coals when the flue gas temperature was
    increased from 300° to 400°F for all particulate control
    configurations.

-   **[Contacts]{.underline}** For further information on this project,
    contact NETL Project Manager, Lynn Brickett, or visit the NETL
    website at
    <http://www.netl.doe.gov/coalpower/environment/index.html>

-   **[Publications]{.underline}**

    -   Pavlish, J.; Pilot-Scale Investigation of Mercury Control
        Technologies for Utilities Burning Lignite Coal. Presented at
        the A&WMA/US EPA/DOE/EPRI Combined Power Plant Air Pollutant
        Control Mega Symposium, Washington, DC, May 19-22, 2003.

[**Return to Project Summary Table**](#EERC_lignite_coal_table)

***DOE/NETL Environmental & Water Resources***

***Mercury Control Technology Project Fact Sheet***

**[Integrated System to Control Primary PM2.5 from Electric Power
Plants]{.underline}**

**[(Mercury Control with the Advanced ElectroCore Particulate
Collector)]{.underline}**

(DC-FC26-00NT-40757)

-   **[Objective]{.underline}** Under its particulate control program
    DOE/NETL is sponsoring the pilot-scale development of LSR
    Technologies' particulate control technology known as ElectroCore.
    In addition to particulate removal, the mercury removal performance
    of the ElectroCore process was evaluated in conjunction with
    powdered activated carbon (PAC) injection.

-   **[Sponsors]{.underline}** The project is being funded by NETL and
    LSR Technologies. Other participants include EPRI, EPA, and Alabama
    Power Company (Southern Company Services).

-   **[Background]{.underline}** The ElectroCore is an electrically
    enhanced mechanical separator designed to be retrofitted downstream
    of an existing ESP to optimize fine particulate collection. The
    ElectroCore process first pre-charges the ash particles and then
    uses combined electrical and centrifugal forces to separate the flue
    gas into "dirty" and "clean" gas streams. The centrifugal
    particulate separation is achieved using cylindrical separators with
    a tangential inlet, a tangential dirty gas outlet, and a dual axial
    clean gas outlet. The centrifugal separation is enhanced by a
    centrally located electrode within the separator. The electrode is
    charged with the same polarity as the ash particles thereby further
    driving the particles to the dirty gas outlet. The dirty gas stream
    can either be re-circulated to the inlet of the upstream ESP or
    diverted to a polishing ESP or FF.

-   **[Project Description]{.underline}** The pilot-scale testing was
    conducted at Alabama Power Company's E.C. Gaston Unit No. 4 located
    in Wilsonville, Alabama. The plant burns a Powder River Basin
    subbituminous coal. The 5,000 acfm pilot plant consists of a dry
    scrubber, water-cooled pre-charger and advanced ElectroCore module.
    In addition to particulate removal, the mercury removal performance
    of the ElectroCore process was evaluated in conjunction with PAC
    injection.

-   **[Schedule]{.underline}** Project started February 2000 and was to
    be completed in June 2002.

-   **[Cost]{.underline}** The total budget cost for the project is
    approximately \$1.6 million. (DOE funding \$1,191,267)

-   **[Status]{.underline}** The pilot-scale testing was conducted from
    November 2001 through February 2002. A final report for the
    ElectroCore particulate collection test results was issued in
    February 2003. A final report on the mercury testing phase of the
    project is not yet available.

-   **[Results To Date]{.underline}** Preliminary test results indicate
    the ElectroCore process captures approximately 90% of the total
    mercury at a PAC injection rate of 7 lb/MMacf.

-   **[Contacts]{.underline}** For further information on this project,
    contact NETL Project Manager, Peter Botros, or visit the NETL
    website at
    <http://www.netl.doe.gov/coalpower/environment/index.html>

-   **[Publications]{.underline}**

    -   Altman, Ralph; Easom, Bruce; Harrison, Wallace Results of
        ElectroCore Pilot Testing at E.C. Gaston Steam Plant. In
        *Proceedings of Air Quality III: Mercury, Trace Elements, and
        Particulate Matter Conference*; Arlington, VA, September 9-12,
        2002.

[**Return to Project Summary Table**](#LSR_electrocore_table)

***DOE/NETL Environmental & Water Resources***

***Mercury Control Technology Project Fact Sheet***

**[In-Situ Sorbent Removal of Mercury: The THIEF Process]{.underline}**

(NETL In-house project)

-   **[Objective]{.underline}** Conduct pilot-scale testing at NETL to
    develop an alternative mercury control technology using an activated
    carbon sorbent produced in-situ at the power plant.

-   **[Sponsors]{.underline}** NETL In-house R&D

-   **[Background]{.underline}** The THIEF process (U.S. Patent No.
    6,521,021) removes mercury from coal combustion flue gas by
    adsorption/absorption onto thermally activated sorbent produced
    in-situ. The sorbent consists of semi-combusted coal, which is
    extracted from the furnace and then injected into the flue gas
    downstream of the air preheater. The thermally activated sorbent
    reacts with the mercury and is removed from the flue gas by the
    downstream particulate control device.

-   **[Project Description]{.underline}** Pilot-scale testing of the
    THIEF process was conducted using the NETL 500 pound-per-hour
    pulverized coal-fired combustion system that includes a furnace, air
    pre-heater, spray dryer, ductwork, and a pulse-jet fabric filter.

-   **[Schedule]{.underline}** On-going in-house research and
    development project.

-   **[Cost]{.underline}** Annual in-house allocation.

-   **[Status]{.underline}** Continued testing of the THIEF process will
    be carried out in the 500-lb/hr combustor while burning different
    coals (i.e. PRB coal).

-   **[Results To Date]{.underline}** The in-situ produced sorbent is
    not as reactive as commercially available activated carbon, but
    pilot-scale testing indicates that mercury removal efficiencies of
    up to 70% are achievable.

-   **[Contacts]{.underline}** For further information on this project,
    contact NETL Project Manager, Bill O'Dowd, or visit the NETL website
    at <http://www.netl.doe.gov/coalpower/environment/index.html>

-   **[Publications]{.underline}**

    -   Pennline, H.W.; Granite, E.J.; Freeman, R.A.; Hargis, R.A.;
        O'Dowd, W.J. A Technique to Control Mercury From Flue Gas.
        Presented at the AIChE Annual Meeting, Indianapolis, IN,
        November 2002.

[**Return to Project Summary Table**](#NETL_thief_table)

***DOE/NETL Environmental & Water Resources***

***Mercury Control Technology Project Fact Sheet***

**[Photochemical Removal of Mercury: The GP-254 Process]{.underline}**

(NETL In-house project)

-   **[Objective]{.underline}** Conduct bench-scale testing at NETL to
    develop an alternative mercury control technology.

-   **[Sponsors]{.underline}** NETL in-house R&D

-   **[Background]{.underline}** The GP-254 process (U.S. patent
    pending) uses 253.7-nm ultraviolet radiation to induce components of
    flue gas to react with elemental mercury and subsequently cause an
    increase in the fraction of oxidized mercury. The oxidized mercury
    species can then be captured near the radiation zone or in
    downstream particulate control or wet FGD pollution control
    equipment.

-   **[Project Description]{.underline}** Small-scale laboratory testing
    using simulated flue gases have been used to demonstrate the
    process.

-   **[Schedule]{.underline}** Complete. Tool base.

-   **[Cost]{.underline}** Exploratory funding as needed.

-   **[Status]{.underline}** Complete.

-   **[Results To Date]{.underline}** See publication.

-   **[Contacts]{.underline}** For further information on this project,
    contact NETL Project Manager, Evan Granite, or visit the NETL
    website at
    <http://www.netl.doe.gov/coalpower/environment/index.html>

-   **[Publications]{.underline}**

    -   Granite, Evan; Pennline, Henry Photochemical Removal of Mercury
        from Flue Gas. *Industrial & Engineering Chemistry Research*,
        October 2002.

[**Return to Project Summary Table**](#NETL_gp254_table)

***DOE/NETL Environmental & Water Resources***

***Mercury Control Technology Project Fact Sheet***

**[Long-Term Operation of a COHPAC System for Removing Mercury from
Coal-Fired Flue Gas]{.underline}**

(DE-FC26-02NT-41591)

-   **[Objective]{.underline}** Conduct a one-year long-term performance
    evaluation of the impact of powdered activated carbon injection on
    the COHPAC fabric filter particulate collection system at Alabama
    Power's E.C. Gaston Plant. Long-term testing will determine whether
    PAC injection with COHPAC is a viable, long-term approach for
    mercury control. The testing will also determine design criteria and
    costs for new retrofit COHPAC systems as well as balance-of-plant
    impacts.

-   **[Sponsors]{.underline}** The project is being funded by NETL and
    ADA Environmental Solutions. Other participants include Southern
    Company, Reaction Engineering, Southern Research Institute, Grubb
    Filtration Testing Services, Hamon Research-Cottrell, EPRI, and
    several utility company sponsors.

-   **[Background]{.underline}** ADA-ES conducted a successful two-week
    demonstration of PAC injection at Gaston in April 2001. The
    objective of this project is to evaluate the long-term effects of
    PAC injection on mercury capture and COHPAC performance. Of
    particular concern during PAC injection is the increased cleaning
    frequency of the COHPAC which could adversely affect filter bag
    life.

-   **[Project Description]{.underline}** The full-scale demonstration
    testing is being conducted at Alabama Power's 270 MW E.C. Gaston
    Unit 3 which burns low sulfur bituminous coal and uses a hot-side
    ESP and COHPAC fabric filter for particulate control. The long-term
    testing will include six-month PAC injection with the existing
    COHPAC filter bags and six-month PAC injection with new
    high-permeation filter bags. Demonstration will also include testing
    of alternate sorbents.

-   **[Schedule]{.underline}** Project started September 2002 and is to
    be completed in October 2005.

-   **[Cost]{.underline}** The total budget cost for the project is
    approximately \$2.4 million. (DOE funding \$1,356,976)

-   **[Status]{.underline}** Baseline testing completed in April 2003.
    PAC injection optimization testing conducted in May 2003.

-   **[Results To Date]{.underline}** Preliminary baseline test results
    include: 1) higher COHPAC cleaning frequency compared to April 2001
    Phase I tests; 2) large variation (0 to 90%) in baseline mercury
    removal; and 3) higher carbon content in COHPAC hopper ash compared
    to Phase I tests. Based on results of optimization testing, the PAC
    injection rate was lowered from 1.5 to 0.3 lb/MMacf. Average mercury
    removal varied from 70 to 95% at 0.3 lbs/MMacf PAC injection rate
    during early May optimization testing.

-   **[Contacts]{.underline}** For further information on this project,
    contact NETL Project Manager, Scott Renninger, or visit the NETL
    website at
    <http://www.netl.doe.gov/coalpower/environment/index.html>

-   **[Publications]{.underline}**

[**Return to Project Summary Table**](#ADA_LT_COHPAC_table)

***DOE/NETL Environmental & Water Resources***

***Mercury Control Technology Project Fact Sheet***

**[Preliminary Field Evaluation of Mercury Using Combustion
Modifications]{.underline}**

(DE-FC26-03NT-41725)

-   **[Objective]{.underline}** Conduct a two-year field evaluation
    using a combination of overfire air (OFA) and coal reburn to achieve
    multi-pollutant control of both NOx and mercury. Combustion
    modifications will be used to increase the reactivity of fly ash to
    enhance mercury adsorption and resultant capture in a downstream ESP
    or FF.

-   **[Sponsors]{.underline}** The project is being funded by NETL and
    General Electric Energy and Environmental Research Corporation (GE
    EER). Other participants include Western Kentucky Energy.

-   **[Background]{.underline}** GE EER has been developing the use of
    OFA and coal reburn as a NOx control technology. Coal reburn
    pilot-scale testing demonstrated that fly ash with unburned carbon
    formed "in situ" can adsorb mercury under certain operating
    conditions.

-   **[Project Description]{.underline}** The field-testing will be
    conducted at Western Kentucky Energy's RD Green Power Station, which
    burns a blend of Illinois bituminous coal and petroleum coke. Field
    measurements of fly ash properties and mercury removal across the
    ESP will be taken on Unit No. 1 after installation of an OFA and
    coal reburn system for NOx control. Data from the Unit No. 1 field
    testing will be used to optimize the design of the NOx control
    system for mercury removal using a 300 KW pilot-scale combustor at
    GE EER's test facility. Results from the pilot-scale testing will be
    used for the design of the OFA and coal reburn system to be
    installed on RD Green Unit No. 2. Mercury removal performance will
    then be tested on Unit No. 2 after installation of the optimized NOx
    control system.

-   **[Schedule]{.underline}** Project started January 2003 and is to be
    completed in July 2004.

-   **[Cost]{.underline}** The total budget cost for the project is
    approximately \$0.8 million. (DOE funding \$489,600)

-   **[Status]{.underline}** Baseline mercury emission testing to be
    conducted in May 2003.

-   **[Results To Date]{.underline}** None available.

-   **[Contacts]{.underline}** For further information on this project,
    contact NETL Project Manager, Peter Botros, or visit the NETL
    website at
    <http://www.netl.doe.gov/coalpower/environment/index.html>

-   **[Publications]{.underline}**

[**Return to Project Summary Table**](#GE_combustion_table)

***DOE/NETL Environmental & Water Resources***

***Mercury Control Technology Project Fact Sheet***

**[Evaluation of Mercury Emissions from Coal-Fired Facilities with
SCR-FGD Systems]{.underline}**

(DE-FC26-02NT-41589)

-   **[Objective]{.underline}** Conduct field testing at ten bituminous
    coal-fired power plants equipped with selective catalytic reduction
    (SCR) control technologies to determine their effect on the
    speciation of mercury in the combustion flue gas and resultant
    enhancement of mercury emissions capture in downstream flue gas
    desulfurization (FGD) control equipment.

-   **[Sponsors]{.underline}** The project is being funded by NETL and
    CONSOL. Other participants include numerous electric utility
    companies that are providing host sites for the testing.

-   **[Background]{.underline}** Previous field testing indicated that
    NOx SCR catalyst converts some of the elemental mercury to oxidized
    mercury in the flue gas and therefore can enhance overall mercury
    capture in downstream pollution control equipment. However, the
    amount of SCR mercury oxidation has been quite variable from
    plant-to-plant. Previous field testing has also indicated some
    inconsistencies in the mercury capture performance of wet FGD
    systems due to possible evolution of elemental mercury. This field
    testing project is necessary to evaluate the effectiveness of SCR to
    promote the oxidation and subsequent capture of elemental mercury in
    full-scale commercial FGD applications.

-   **[Project Description]{.underline}** Conduct mercury speciation
    field-testing at ten bituminous coal-fired power plants to measure
    the level of mercury oxidation across the SCR and subsequent removal
    in the downstream FGD system. The 27-month long program will include
    testing at five plants equipped with an SCR and wet limestone FGD,
    three plants with an SCR and wet lime FGD, and two plants with an
    SCR and dry lime FGD.

-   **[Schedule]{.underline}** Project started September 2002 and is to
    be completed in September 2005.

-   **[Cost]{.underline}** The total budget cost for the project is
    approximately \$0.7 million. (DOE funding \$584,419)

-   **[Status]{.underline}** Two plants had been tested as of 5/30/03.

-   **[Results To Date]{.underline}** None available.

-   **[Contacts]{.underline}** For further information on this project,
    contact NETL Project Manager, Peter Botros, or visit the NETL
    website at
    <http://www.netl.doe.gov/coalpower/environment/index.html>

-   **[Publications]{.underline}**

[**Return to Project Summary Table**](#CONSOL_SCR_FGD_table)

***DOE/NETL Environmental & Water Resources***

***Mercury Control Technology Project Fact Sheet***

**[Direct Measurement of Mercury Reactions in Coal Power Plant
Plumes]{.underline}**

(DE-FC26-03NT-41724)

-   **[Objective]{.underline}** Conduct field testing to characterize
    the speciation of mercury in the stack plume of a coal-fired power
    plant.

-   **[Sponsors]{.underline}** The project is being funded by NETL and
    EPRI. Other participants include UNDEERC, Frontier Geosciences and
    We Energies.

-   **[Background]{.underline}** The proportions of elemental and
    oxidized species of mercury emissions from coal-fired power plants
    may influence the relative location of their potential environmental
    impact. Gaseous elemental mercury is relatively unreactive and can
    persist in the atmosphere for periods of months to years before
    returning to the surface environment. However, gaseous oxidized
    mercury is more reactive and likely to return to the surface
    environment locally or regionally via wet or dry deposition.
    However, atmospheric reactions might occur after release from the
    stack that alters the proportion of elemental and oxidized mercury
    species. Previous analysis of mercury concentrations measured at an
    ambient monitor located about 15 km south of Southern Company's
    Bowen Plant suggested that a significant portion of Bowen's oxidized
    mercury stack emissions may have been reduced to elemental mercury
    while being transported to the monitoring site.

-   **[Project Description]{.underline}** Conduct field testing to
    characterize the speciation of mercury in the stack plume of We
    Energies' Pleasant Prairie Plant. The tests include simultaneous
    mercury measurements in the stack and stack plume using
    aircraft-borne instruments. The in-stack and stack plume
    measurements will be compared to determine whether the speciation of
    mercury changes as it is transported downwind in the plume. In
    addition to the in-stack and stack plume mercury measurements, a
    plume dilution sampling device is being used in an attempt to
    simulate the cooling and dilution processes that occur in the stack
    plume. If results of the plume dilution sampling device are
    comparable to the stack plume measurements it could be used to
    estimate the mercury speciation changes for other plants.

-   **[Schedule]{.underline}** Project started March 2003 and is to be
    completed in September 2004.

-   **[Cost]{.underline}** The total budget cost for the project is
    approximately \$0.8 million. (DOE funding \$648,154)

-   **[Status]{.underline}** Stack plume measurements scheduled to be
    conducted in July 2003.

-   **[Results To Date]{.underline}** None available.

-   **[Contacts]{.underline}** For further information on this project,
    contact NETL Project Manager, Bill Aljoe, or visit the NETL website
    at <http://www.netl.doe.gov/coalpower/environment/index.html>

-   **[Publications]{.underline}**

[**Return to Project Summary Table**](#EPRI_plume_table)

***DOE/NETL Environmental & Water Resources***

***Mercury Control Technology Project Fact Sheet***

**[Evaluation of Mercury Speciation in a Power Plant
Plume]{.underline}**

(DE-FC26-98FT40321-54)

-   **[Objective]{.underline}** Conduct field testing to characterize
    the speciation of mercury in the stack plume of a coal-fired power
    plant.

-   **[Sponsors]{.underline}** The project is being funded by NETL and
    UNDEERC. Other participants include EPRI, Frontier Geosciences, TVA
    and Southern Company.

-   **[Background]{.underline}** The proportions of elemental and
    oxidized species of mercury emissions from coal-fired power plants
    may influence the relative location of their potential environmental
    impact. Gaseous elemental mercury is relatively unreactive and can
    persist in the atmosphere for periods of months to years before
    returning to the surface environment. However, gaseous oxidized
    mercury is more reactive and likely to return to the surface
    environment locally or regionally via wet or dry deposition.
    However, atmospheric reactions might occur after release from the
    stack that alters the proportion of elemental and oxidized mercury
    species. Previous analysis of mercury concentrations measured at an
    ambient monitor located about 15 km south of Southern Company's
    Bowen Plant suggested that a significant portion of Bowen's oxidized
    mercury stack emissions may have been reduced to elemental mercury
    while being transported to the monitoring site.

-   **[Project Description]{.underline}** Conduct field testing to
    characterize the speciation of mercury in the stack plume of
    Southern's Bowen Plant. The tests include simultaneous mercury
    measurements in the stack and stack plume using aircraft-borne
    instruments. The in-stack and stack plume measurements will be
    compared to determine whether the speciation of mercury changes as
    it is transported downwind in the plume. In addition to the in-stack
    and stack plume mercury measurements, a plume dilution sampling
    device is being used in an attempt to simulate the cooling and
    dilution processes that occur in the stack plume.

-   **[Schedule]{.underline}** Project started October 2002 and was
    completed in March 2003.

-   **[Cost]{.underline}** The total budget cost for the project is
    approximately \$68,000. (DOE funding \$27,324)

-   **[Status]{.underline}** Testing completed in October 2002.

-   **[Results To Date]{.underline}** None available.

-   **[Contacts]{.underline}** For further information on this project,
    contact NETL Project Manager, Bill Aljoe, or visit the NETL website
    at <http://www.netl.doe.gov/coalpower/environment/index.html>

-   **[Publications]{.underline}**

[**Return to Project Summary Table**](#EERC_plume_table)

***DOE/NETL Environmental & Water Resources***

***Mercury Control Technology Project Fact Sheet***

**[Oxidation of Mercury Across SCR Catalysts in Coal-Fired Power
Plants]{.underline}**

**[Burning Low-Rank Coals]{.underline}**

(DE-FC26-02NT-41728)

-   **[Objective]{.underline}** Conduct pilot-plant testing to determine
    the effect of various NOx SCR catalysts on mercury speciation for
    plants that burn subbituminous Powder River Basin coal.

-   **[Sponsors]{.underline}** The project is being funded by NETL and
    Reaction Engineering. Other participants include EPRI, Ceramics
    GmbH, and American Electric Power (AEP).

-   **[Background]{.underline}** Previous field testing indicated that
    NOx SCR catalyst converts some of the elemental mercury to oxidized
    mercury in the flue gas and therefore can enhance overall mercury
    capture in downstream pollution control equipment. However, the
    amount of SCR mercury oxidation has been quite variable from
    plant-to-plant and there is limited test data available for PRB coal
    applications. This pilot-plant testing is necessary to evaluate the
    effectiveness of various SCR catalysts to promote the oxidation of
    elemental mercury in PRB coal applications.

-   **[Project Description]{.underline}** Conduct a six-month-long
    pilot-scale mercury speciation test for five commercially available
    NOx SCR catalysts using a flue gas slipstream at AEP's 1300 MW
    Rockport Power Plant Unit 1, which burns a subbituminous Powder
    River Basin coal. Parametric testing will evaluate the effect of
    space velocity (residence time) and ammonia feed rate on mercury
    oxidation across the SCR catalysts.

-   **[Schedule]{.underline}** Project started February 2003 and is to
    be completed in August 2003.

-   **[Cost]{.underline}** The total budget cost for the project is
    approximately \$120,000. (DOE funding \$69,698)

-   **[Status]{.underline}** The initial mercury speciation testing was
    completed in April 2003.

-   **[Results To Date]{.underline}** Preliminary results from the
    initial mercury speciation testing are under review. Some general
    observations from the S-CEM measurements are: 1) mercury oxidation
    ranged from approx. 0% to 50% across the five catalysts at a space
    velocity of 5,700 hr^-1^, 2) mercury oxidation increased to 60% to
    80% without ammonia feed, 3) an unexplained 10% to 40% reduction of
    total mercury was measured across the catalysts, 4) mercury
    oxidation decreases as space velocity increases.

-   **[Contacts]{.underline}** For further information on this project,
    contact NETL Project Manager, Jose Figueroa, or visit the NETL
    website at
    <http://www.netl.doe.gov/coalpower/environment/index.html>

-   **[Publications]{.underline}**

[**Return to Project Summary Table**](#Reaction_SCR_table)

***DOE/NETL Environmental & Water Resources***

***Mercury Control Technology Project Fact Sheet***

**[Mercury and Air Toxics Element Impacts of Coal
Combustion]{.underline}**

**[Byproduct Disposal and Utilization]{.underline}**

(DE-FC26-03NT-41727)

-   **[Objective]{.underline}** Conduct laboratory and field-testing to
    evaluate the potential release of mercury and other air toxic
    elements associated with the disposal and commercial use of various
    ash and FGD coal utilization by-products from conventional and
    advanced pollution control systems.

-   **[Sponsors]{.underline}** The project is being funded by NETL and
    UNDEERC.

-   **[Background]{.underline}** There is limited data available on the
    environmental acceptability of CUBs produced at plants with various
    conventional and advanced emission control systems.

-   **[Project Description]{.underline}** CUBs from bituminous,
    subbituminous, and lignite fuels will be included in the evaluation.
    The project includes a literature search, selection of analytical
    methods, selection of CUB samples, chemical and physical
    characterization of samples, laboratory testing of release
    mechanisms, and field investigations. The potential release
    mechanisms to be evaluated include leaching, vaporization at ambient
    and elevated temperature, and biologically induced releases.

-   **[Schedule]{.underline}** Project started January 2003 and is to be
    completed in January 2006.

-   **[Cost]{.underline}** The total budget cost for the project is
    approximately \$1.5 million. (DOE funding \$1,200,000)

-   **[Status]{.underline}** A project kick-off meeting was conducted in
    April 2003.

-   **[Results To Date]{.underline}** None available.

-   **[Contacts]{.underline}** For further information on this project,
    contact NETL Project Manager, Nam Lee, or visit the NETL website at
    <http://www.netl.doe.gov/coalpower/environment/index.html>

-   **[Publications]{.underline}**

[**Return to Project Summary Table**](#EERC_byproducts_table)