### Re: PM Speciation and SO3 Don

_ Shepherd to: Michael Feldman 11/01/2010 09:38 AM Cc: Elizabeth.Kuehn History: This message has been forwarded.

5 attachments

revised SJGS #2 Dry-Bottom PC w FGD+FF PM speciation profile.xlsx

revised SJGS #3 Dry-Bottom PC w FGD+FF PM speciation profile.xlsx

revised SJGS #1 Dry-Bottom PC w FGD+FF PM speciation profile.xlsx

revised SJGS #4 Dry-Bottom PC w FGD+FF PM speciation profile.xlsx

SJGS #1 Dry-Bottom PC w FGD+FF PM speciation profile.xls

Michael,

Thanks for catching my errors--here are the revised PM workbooks for SJGS--changes are in orange:

(See attached file: revised SJGS #2 Dry-Bottom PC w FGD+FF PM speciation profile.xlsx)(See attached file: revised SJGS #3 Dry-Bottom PC w FGD+FF PM speciation profile.xlsx)(See attached file: revised SJGS #1 Dry-Bottom PC w FGD+FF PM speciation profile.xlsx)(See attached file: revised SJGS #4 Dry-Bottom PC w FGD+FF PM speciation profile.xlsx)

Don Shepherd National Park Service Air Resources Division 12795 W. Alameda Pkwy. Lakewood, CO 80228 Phone: 303-969-2075 Fax: 303-969-2822 E-Mail: don_shepherd@nps.gov

Feldman.Michael@e pamail.epa.gov
To 10/29/2010 10:31 Don_Shepherd@nps.gov AM cc

Subject Re: PM Speciation and SO3Don - I am attaching a spreadsheet that you put together for the San Juan Generating Station. I have some questions about the factors used in the EPRI calculation. Specifically the F2 factors for the SO3 from the boiler and from the SCR. The other worksheets for the other units are available at http://www.nmenv.state.nm.us /aqb/reghaz/Regional-Haze_index.html

Please give me a call when you have a moment to discuss this.

Thank you,

Michael Feldman Environmental Engineer Air Planning Section U.S. EPA Region 6, 6PD-L Phone: 214-665-9793 feldman.michael@epa.gov

From: Don_Shepherd@nps.gov

To: Michael Feldman/R6/USEPA/US@EPA

Cc: Dean_Gillam@fws.gov

Date: 10/20/2010 11:47 AM

Subject: Re: PM Speciation and SO3

Michael,

I am attaching a modified version of our PM speciation workbook for dry-bottom boilers to incorporate the EPRI spreadsheets for estimating H2SO4. (There is no need to adjust the condensible inorganic PM in this case because AP-42 already gives us the 80/20 split between inorganic and organic condensible PM for unscrubbed EGUs.) In this case, i entered the coal data shown below, but left the heat input at the 1,000 mmBtu/hr default--that does not affect the PM speciation profile, but it does affect the actual emission rates (lb/hr), so you will need to enter heat input for each unit. I assumed that all units had cold-side ESPs, so the penetrationfactor became 0.73. This penetration factor decreases the amount of H 2 S O 4 released from the boiler, but does not affect the amount of inorganic and organic condensibles because that is already accounted for in the AP-42 emission factor. If you do want to know how much of the inorganic condensible PM is H2SO4, that can be found in cell B25 of the "Calculate" tab.

(See attached file: Mofdified Dry-Bottom PC w ESP PM speciation profile.xlsx)

The amount of H2SO4 emitted should always be less than the amount of inorganic condensible PM because H2SO4 is a subset of inorganic condensible
PM.

Don Shepherd National Park Service Air Resources Division 12795 W. Alameda Pkwy. Lakewood, CO 80228 Phone: 303-969-2075 Fax: 303-969-2822 E-Mail: don_shepherd@nps.gov

Feldman.Michael@e pamail.epa.gov
To 10/19/2010 01:44 don_shepherd@nps.gov PM cc

Subject PM Speciation and SO3

Don - The summary below is information on the calculations for PM and H2SO4 performed by Trinity Consultants for OG&E and AEP. This summary is based on the information in the attached documents that were submitted to ODEQ as part of their BART Application. Please let me know your thoughts on their calculations and the proposed use of the EPRI method and the factors given in the table below. The EPRI method yields SO3 emissions much lower than calculated with the NPS speciation worksheets. Please give me a call to discuss or if you have any questions.

Thank you,

Michael FeldmanOklahoma CALPUFF modeling for OG&E Sooner and Muskogee and AEP Northeastern units.

CALPUFF Emission assumptions:

1) OG&E assumed 1% conversion of SO2 to SO3 across the boiler and calculated PM10 speciation using NPS Speciation AP-42 spreadsheets ( http://www.nature.nps.gov/air/ permits/ect/ectCoalFiredBoiler.cfm). The speciation worksheet was used to obtain the fractions of PM emissions that are SO3, Coarse, Fine, EC, and SOA. Inorganic condensable PM was assumed to be SO3 and this amount was added to the SO4 calculated from the 1% conversion across the boiler. OG&E used the NPS speciation worksheet for wet bottom boilers with ESP for all control scenarios. The Sooner and Muskogee units are dry bottom with ESP. Furthermore, OG&E did not input the necessary coal quality (heating value, % sulfur, % ash), and heat input needed to calculate the correct PM speciation from the NPS worksheets and just used the default values of 10000 Btu/lb coal with 1% S and 10% ash.

2) For AEP Northeastern, the speciation worksheet was used to obtain the fractions of PM emissions that are SO3, Coarse, Fine, EC, and SOA. Inorganic condensable PM was assumed to be SO3. AEP used the dry bottom ESP NPS worksheet, but did not input the necessary coal quality (heating value, % sulfur, % ash), and heat input needed to calculate the PM speciation from the NPS worksheets and just used the default values of 10000 Btu/lb coal with 1% S and 10% ash. In addition, SO4 from SO2 was calculated based on an assumption of 3ppm in the flue gas.

We propose to use the EPRI method to calculate H2SO4 and account for removal by the downstream equipment. The NPS speciation worksheets will be used to calculate PM emissions by size (PM8, PM4.25, PM1.88, PM1.25, PM0.813, PM0.625). (These species will be converted to PMC, PMfine, EC and SOA in postutil). |-----------------------------------------------------------+-------------| | EPRI method parameter | value | |-----------------------------------------------------------+-------------| | Worst case Sulfur | 0.48% | |-----------------------------------------------------------+-------------| | Worst case Ash | 7.5% | |-----------------------------------------------------------+-------------| | Heating value | 8000 Btu/lb | |-----------------------------------------------------------+-------------| | F1 (Fuel Impact Factor, subbituminous/PRB all boilers) | 0.0019 | |-----------------------------------------------------------+-------------| | F2 (Technology Impact factors): | | |-----------------------------------------------------------+-------------| | Air Heater (PRB)| 0.36 | |-----------------------------------------------------------+-------------| | Cold-side ESP (PRB)| 0.72 | |-----------------------------------------------------------+-------------| | Wet spray tower (PRB)| 0.4 | |-----------------------------------------------------------+-------------| | Dry FGD and baghouse| 0.01 | |-----------------------------------------------------------+-------------|Michael Feldman Environmental Engineer Air Planning Section U.S. EPA Region 6, 6PD-L Phone: 214-665-9793 feldman.michael@epa.gov(See attached file: OG&E_Sooner_BART_Emission_summary.pdf)(See attached file: AEP-PSO_Northeast_BART_Emission_summary.pdf)(See attached file: OG&E_Muskogee_BART_Emission_summary.pdf)[attachment "Mofdified Dry-Bottom PC w ESP PM speciation profile.xlsx" deleted by Michael Feldman/R6/USEPA/US] [attachment "OG&E_Sooner_BART_Emission_summary.pdf" deleted by Michael Feldman/R6/USEPA/US] [attachment "AEP-PSO_Northeast_BART_Emission_summary.pdf" deleted by Michael Feldman/R6/USEPA/US] [attachment "OG&E_Muskogee_BART_Emission_summary.pdf" deleted by Michael Feldman/R6/USEPA/US]

(See attached file: SJGS #1 Dry-Bottom PC w FGD+FF PM speciation profile.xls)