### Emissions for Modeling Scenarios for EPA's BART Proposal for Navajo Generating Station EPA, May 2012 Note that the numbering for the control scenarios is different from that used in the 2009 ANPRM.
**Code Name**  **Description Short Desc.**  N0 Baseline 2001 - 2003 baseline Baseline N1 Control Option 1 LNB + SOFA on Units 1 - 3, 0.24 lb/MMBtu LNB N2 Control Option 2 SCR+LNB+SOFA on Units 1 - 3 (0.05 lb/MMBtu), SO2 conversion 0.67% SCR 0.05 lb/MMBtu N3 Control Option 3 SCR+LNB+SOFA on Units 1 - 3 (0.08lb/MMBtu), SO2 conversion 0.5% SCR 0.08, SO3 0.5% N4 Control Option 4 SCR+LNB+SOFA on Units 1 - 3 (0.05 lb/MMBtu); SRP's Air Preheater penetration = 0.9 SCR, APH p=0.9 N5 Control Option 5 SCR+LNB+SOFA on Unit 1 only (0.05 lb/MMBtu); LNB+SOFA on Unit 2 & 3 SCR on 1, LNB on 2&3 N6 Control Option 6 SCR+LNB+SOFA on Units 1 & 3(0.05 lb/MMBtu); LNB+SOFA on Unit 2 SCR on 1&3, LNB on 2 N7 Control Option 7 SCR as in N2, but with SCR placed *after* the ESP , as in SRP assumption SCR after ESP N8 Control Option 8 SNCR+LNB+SOFA on Units 1 - 3, NOx at 0.18 lb/MMBtu SNCR 0.18 lb/MMBtu N9 Control Option 9 SNCR+LNB+SOFA on Units 1 - 3, NOx at 0.15 lb/MMBtu SNCR 0.15 lb/MMBtu The last spreadsheet tab, "Baseline stack data", has stack parameters**Ab breviat** 

**ion** Sheet/Tab name NOx, lb/hr Em ission rank Base n0 Base 12661 1 LNB n1 LNB 6570 2 SCR n2 SCR 1369 8 SCRhi n3 SCRhi 2190 7 SCRp9 n4 SCRp9 1369 9 SCRu1 n5 SCRu1 4899 4 SCRu13 n6 SCRu13 3159 6 SCRpost n7 SCR postESP 1369 10 SNCRhi n8 SNCR 0.18 4928 3 SNCRlo n9 SNCR 0.15 4106 5**EPA revisions to values used in ANPRM**

fine total fine soil EC MMBtu/day MMBtu/hr % ton/day lb/hr lb/MMBtu % reduction ton/day lb/hr lb/MMBtu lb/MMBtu (e) lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr

Navajo 1 750 MW , PC,

biituminous coal, dry bottom, tangential fired, hot side ESP, wet FGD 211,074 8,795 0.593 5.85 487.75 0.055 #N/A 51.26 4,271.42 0.486 0.0260 228.66 153.20 (f) 86.89 (f) 66.31 (f) 63.9 (g) 2.45 (g) 37.55 (h) 2.37 (i) 2.32 35.18 (j) 190.76

Navajo 2 750 MW , PC,

biituminous coal, dry bottom, tangential fired, hot side ESP, wet FGD 226,163 9,423 0.593 6.32 526.92 0.056 #N/A 50.49 4,207.50 0.446 0.0210 197.89 132.59 (f) 75.20 (f) 57.39 (f) 55.3 (g) 2.12 (g) 40.24 (h) 2.54 (i) 2.49 37.69 (j) 172.82

Navajo 3 750 MW , PC,

biituminous coal, dry bottom, tangential fired, hot side ESP, wet FGD 219,778 9,157 0.593 6.91 576.17 0.063 #N/A 50.18 4,181.67 0.457 0.0310 283.88 190.20 (f) 107.87 (f) 82.33 (f) 79.3 (g) 3.05 (g) 39.10 (h) 2.47 (i) 2.42 36.63 (j) 229.30

  Below** **are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately** (a) Maximum daily 24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02. Total PM10 H2SO4 coarse total SO4 Maximum Sulfur Content (b) Facility Unit Maximum NOx Emissions (d) 

### Maximum Emissions Including Speciated PM **10**

### Emissions

Filterable PM 10 Condensable PM 10 Fine Maximum Filterable PM Emissions Description 

### Navajo Units 1, 2, and 3 **Baseline Conditions**

Maximum SO2 Emissions (c) organic

(j) Organic condensible PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. EPRI (2008) Eqn 4-2b indicates that 95% of fuel sulfur is converted to SO2. Maximum Heat Input (a)

(f) For a dry bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. (e) Maximum of 6 stack test results for the 2001 to 2006 period. (h) Total condensible PM10 is the sum of H2SO4 and organic condensible PM10 emissions. (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiam Battye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. total

(d) Maximum daily 24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. (c) Maximum daily 24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or

09000064811c2027 

### n0 Base 1/18/2013**EPA revisions to values used in ANPRM**

fine total fine soil EC MMBtu/day MMBtu/hr % ton/day lb/hr lb/MMBtu % reduction ton/day lb/hr lb/MMBtu lb/MMBtu (e) lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr

Navajo 1 750 MW , PC,

bituminous coal, dry bottom, tangential fired, **LNB** , SOFA, hot side ESP, wet FGD 211,074 8,795 0.593 5.85 487.75 0.055 51% 25.33 2,110.74 0.240 0.0260 228.66 153.20 (f) 86.89 (f) 66.31 (f) 63.9 (g) 2.45 (g) 37.55 (h) 2.37 (i) 2.32 35.18 (j) 190.76

Navajo 2 750 MW , PC,

bituminous coal, dry bottom, tangential fired, **LNB** , SOFA, hot side ESP, wet FGD 226,163 9,423 0.593 6.32 526.92 0.056 46% 27.14 2,261.63 0.240 0.0210 197.89 132.59 (f) 75.20 (f) 57.39 (f) 55.3 (g) 2.12 (g) 40.24 (h) 2.54 (i) 2.49 37.69 (j) 172.82

Navajo 3 750 MW , PC,

bituminous coal, dry bottom, tangential fired, **LNB** , SOFA, hot side ESP, wet FGD 219,778 9,157 0.593 6.91 576.17 0.063 47% 26.37 2,197.78 0.240 0.0310 283.88 190.20 (f) 107.87 (f) 82.33 (f) 79.3 (g) 3.05 (g) 39.10 (h) 2.47 (i) 2.42 36.63 (j) 229.30

(a) Maximum daily 24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02.
(d) Maximum daily/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. (c) Maximum daily 24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or malfunction. (e) Maximum of 6 stack test results for the 2001 to 2006 period. (h) Total condensable PM10 is the sum of H2SO4 and organic condensible PM10 emissions. (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiam Battye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (f) For a dry bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. total Maximum Heat Input (a)

(j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. EPRI (2008) Eqn 4-2b indicates that 95% of fuel sulfur is converted to SO2.   Below** **are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately** (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. coarse SO4 

### Maximum Emissions Including Speciated PM **10**

### Emissions

Total PM 10 Filterable PM 10 Condensable PM 10

Fine Maximum Filterable PM Emissions Description Unit total Maximum Sulfur Content (b) 

### Navajo Units 1, 2, and 3 **Control Option 1: Low NOx Burners and Separated Overfire A ir** 

H2SO4 organic Facility Maximum SO2 Emissions (c) Maximum NOx Emissions (d)

09000064811c2027 

### n1 LNB 1/18/2013

### Control Option 2: Low**NOx Burners, Separated Overfire A ir, and Selective Cataly** **tic Reduction (Units 1, 2 & 3) _ EPA modified to use Ultra-low** **activity cataly** **st and NOx limit 0.05 lb/MMBtu EPA**  **revisions to values used in A NPRM** 

MMBtu/day MMBtu/hr % ton/day lb/hr lb/MMBtu % reduction ton/day

Navajo 1 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, LNB, SOFA, **SCR** , hot side ESP, wet FGD 211,074 8,795 0.593 5.85 487.75 0.055 90% 5.28

Navajo 2 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, LNB, SOFA, **SCR** , hot side ESP, wet FGD 226,163 9,423 0.593 6.32 526.92 0.056 89% 5.65

Navajo 3 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, LNB, SOFA, **SCR** , hot side ESP, wet FGD 219,778 9,157 0.593 6.91 576.17 0.063 89% 5.49 Maximum Heat Input (a) Maximum Sulfur Content (b)

(a) Maximum daily

24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02. 

## Maximum Emissions Including Speciated PM

**Navajo Units 1, 2, and 3**

Facility Unit Description



### ** Below**are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately** (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. Maximum SO2 Emissions (c) Maximum NOx EmissionsUnit conversion for ammonia slip from ppmvd to lb/hr NH3 0.75 ppm vd at 6% O2 Method 19 (SO2 removal efficiency) formula, Eq. 19-1:

0.00045 lb/MMBtu E = Cd*Fd*20.9/(20.9 - %O2d) unit 1 3.99 lb/hr Cd = Pollutant concentration, dry basis unit 2 4.27 lb/hr Fd = volum es of combustion components per unit of heat content unit 3 4.15 lb/hr %O2d = Concentration of oxygen on a dry basis, percent. Table 19-2 gives F factor for bituminous coal as Fd = 9780 sdcf/10^6 Btu

(6) The 0.63 ESP penetration is applied to H2SO4 before the ammonia reaction, which mainly occurs in the lower temperatures of the air preheater. SCR conversion of SO2 to SO3 99.50% = fraction SO2 remaining after 3 layers, corresponding to 0.5% conversion layers conversion

1 0.17% 2 0.33% 3 0.50% 4 0.67% (h) Total condensable PM10 is the sum of H2SO4 and organic condensable PM10 emissions. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or malfunction.

(2) in sulfuric acid calculation, revised penetration factor for hot-side ESP from 1 (used in ANPRM) to 0.63. (f) For a dry

bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiam Battye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002.



### EPA revisions to Values used in ANPRM (3-7-11) (e) Maximum of 6 stack test results for the 2001 to 2006 period.
(i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. EPRI (2008) Eqn 4-2b indicates that 95% of fuel sulfur is converted to SO2.

(1) set HCl and HF to zero (j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998. (d) Maximum daily

/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01.

(5) Ammonia slip calculation only affects split between H2SO4 and ammonium sulfate/bisulfate. Since in this case there is no ammonia slip, and controls are assumed to affect all these the same way, the split is irrelevant, and only total am ount of SO4 matters for modeling. (Since all SO4 forms are assumed to be affected the same way, the SO4 for modeling can also be calculated directly from H2SO4 * 96.06/98.08.) (3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for PRB coal (strongly

alkaline coal) (4) 0.67% SO2 to SO3 conversion efficiency : Three layers give 0.5% conversion; may not have 4th till 3rd year, but conservatively assume all in four place at start. 1 - (1 - 0.005)^(3/4) or 0.005*4/3 are both about 0.0067 = 0.67%, see below (k) Ammonia slip is 0.75 ppmvd at 6% O2 for SCR. (l) Ammonia is assumed to react with SO4 to form ammonium sulfate per EPRI 2008 if the molecules of NH3 are at least twice those of H2SO4; otherwise, ammonium bisulfate is formed.Penetration factors H2SO4 AbS and AS PM, general p % ctrl p % ctrl p % ctrl hot-side ESP 0.63 37% 0.01 99% 0.01 99% Air Preheater 0.50 50% 0.75 25% Wet FGD (scrubber) 0.47 53% 0.50 50% EPRI H2SO4 doc EPRI NH3 doc

### Control Option 2: Low**NOx Burners, Separated Overfire A ir, and Selective Cataly** **tic Reduction (Units 1, 2 & 3) _ EPA**

**modified to use Ultra-low activity**  **cataly st and NOx limit 0.05 lb/MMBtu** 

fine total fine soil EC lb/hr lb/MMBtu lb/MMBtu (e) lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr

439.74 0.050 0.026 228.66 153.20 (f) 86.89 (f) 66.31 (f) 63.9 (g) 2.45 (g) 51.88 (h) 16.70 (i) 35.18 (j)

471.17 0.050 0.021 197.89 132.59 (f) 75.20 (f) 57.39 (f) 55.3 (g) 2.12 (g) 55.59 (h) 17.89 (i) 37.69 (j)

457.87 0.050 0.031 283.88 190.20 (f) 107.87 (f) 82.33 (f) 79.3 (g) 3.05 (g) 54.02 (h) 17.39 (i) 36.63 (j) total coarse Fine total

(a) Maximum daily

24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02. H2SO4 

## Maximum Emissions Including Speciated PM **10**

## Emissions

**Navajo Units 1, 2, and 3**

Filterable PM 10 Condensable PM 10 organic Maximum Filterable PM Em issions



### ** Below**are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately** (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. Maximum NOx Emissions (d)Method 19 (SO2 removal efficiency) formula, Eq. 19-1: Atm osphere is 20.9% oxygen Cd = Pollutant concentration, dry basis Am mo nia M.W . is 17 lb/lb.mol Fd = volum es of combustion components per unit of heat content 385 ft3/lb-mol = volume of 1 ft3 of gas at STP %O2d = Concentration of oxygen on a dry basis, percent. Table 19-2 gives F factor for bituminous coal as Fd = 9780 sdcf/10^6 Btu

(6) The 0.63 ESP penetration is applied to H2SO4 before the ammonia reaction, which mainly occurs in the lower temperatures of the air preheater. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or malfunction. (f) For a dry

bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x (d) Maximum daily

/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01.

(5) Ammonia slip calculation only affects split between H2SO4 and ammonium sulfate/bisulfate. Since in this case there is no ammonia slip, and controls are assumed to affect all these the same way, the split is irrelevant, and only total am ount of SO4 matters for modeling. (Since all SO4 forms are (3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for (4) 0.67% SO2 to SO3 conversion efficiency : Three layers give 0.5% conversion; may not have 4th till 3rd year, but conservatively assume all in four place at start. 1 - (1 - 0.005)^(3/4) or 0.005*4/3 are both about 0.0067 = 0.67%, see below (l) Ammonia is assumed to react with SO4 to form ammonium sulfate per EPRI 2008 if the molecules of NH3 are at least twice those of H2SO4; otherwise, ammonium bisulfate is formed.lb/hr lb/hr lb m ole/hr lb m ole/hr mo le ratio lb m ole/hr lb m ole/hr lb m ole/hr lb m ole/hr lb/hr lb/hr lb/hr

71.06 3.99 (k) 0.234 0.724 0.323 0.490 0.234 0.000 0.000 **0.00** 17.64 **16.35**

76.13 4.27 (k) 0.251 0.776 0.323 0.525 0.251 0.000 0.000 **0.00** 18.90 **17.52**

73.99 4.15 (k) 0.244 0.754 0.323 0.510 0.244 0.000 0.000 **0.00** 18.36 **17.03** [NH3] after reaction H2SO4 + AbS + AS post-control [H2SO4] after reaction [NH3] / [H2SO4] ratio Total Effective SO4 for modeling [H2SO4] H2SO4 before NH3 interaction, after ESP [AS] or [(NH4)2SO 4] after reaction NH3 Slip [AbS] or [NH4HSO4] after reaction Am mo nia slip and reaction with sulfuric acid, for Net ammonia slip and Modeling SO4 Net NH3 after reaction & WF GD [NH3](c) Maximum daily 24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or malfunction.

### For copying to Word version of tables Highlight num bers portion of table here, copy; then goto W ord, highlight num bers section of its table, paste

**Control Option 2: SCR Units 1 - 3**
H2SO4 HCl HF HCl + HF HCl+HF+ Pm fine Max Heat Input SO2 NOx H2SO4 lb/hr lb/m mbtu lb/m mbtu lb/Mm btu lb/hr new PM fine MMBtu/hr lb/MMBtu lb/MMBtu lb/MMBtu

**206.02 0.0019**  0 0 0 63.86 Unit 1 8,795 0.06 0.05 0.0019

189.178 **0.0019** 0 0 0 55.27 Unit 2 9,423 0.06 0.05 0.0019

245.192 **0.0019** 0 0 0 79.28 Unit 3 9,157 0.06 0.05 0.0019

Max Heat Input SO2 NOx H2SO4 Total PM10MMBtu/hr lb/hr lb/hr lb/hr Unit 1 8,795 487.75 439.74 16.70 Unit 2 9,423 526.92 471.17 16.70 Unit 3 9,157 576.17 457.87 16.70 1368.78Highlight num bers portion of table here, copy; then goto W ord, highlight num bers section of its table, paste

Filterable PM10 Condensable PM10 (CPM) Filterable PM NH3 PM coarse PM fine soil PM fine

EC inorganic

(SO4) organic

(SOA) Max Stack

Test lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu

0 0.010 0.007 0.00028 0.0019 0.0040 0.026

0 0.008 0.006 0.00023 0.0019 0.0040 0.021

0 0.012 0.009 0.00033 0.0019 0.0040 0.031

Filterable PM10 Condensable PM10 (CPM) 

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals NH3 PM coarse PM fine soil PM fine

EC inorganic

(SO4) organic

(SOA) Max Stack

Testlb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr scen SRCNAM SO2 SO4 NOX HNO3

0 86.89 63.86 2.45 16.35 35.18 228.66 n2 NGS1 487.75 16.35 439.74 0 0 75.20 55.27 2.12 17.52 37.69 197.89 n2 NGS2 526.92 17.52 471.17 0 0 107.87 79.28 3.05 17.03 36.63 283.88 n2 NGS3 576.17 17.03 457.87 0

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimalsNO3 SOA PMF PMC EC

0 35.18 63.86 86.89 2.45 0 37.69 55.27 75.20 2.12 0 36.63 79.28 107.87 3.05**Control Option 3: SCR Units 1 - 3; high limit 0.08 lb/MMBtu** Filterable PM10 Condensable PM10 (CPM) Filterable PM Max Heat Input SO2 NOx H2SO4 NH3 PM coarse PM fine soil PM fine

EC inorganic

(SO4) organic

(SOA) Max Stack

Test MMBtu/hr lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu

Unit 1 8,795 0.06 0.08 0.0015 0 0.010 0.007 0.00028 0.0015 0.0040 0.026

Unit 2 9,423 0.06 0.08 0.0015 0 0.008 0.006 0.00023 0.0015 0.0040 0.021

Unit 3 9,157 0.06 0.08 0.0015 0 0.012 0.009 0.00033 0.0015 0.0040 0.031

Filterable PM10 Condensable PM10 (CPM) 

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals Max Heat Input SO2 NOx H2SO4 NH3 PM coarse PM fine soil PM fine

EC inorganic

(SO4) organic

(SOA) Max Stack

Test MMBtu/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr scen Unit 1 8,795 487.75 703.58 13.06 0 86.89 63.86 2.45 12.79 35.18 228.66 n3 Unit 2 9,423 526.92 753.88 14.00 0 75.20 55.27 2.12 13.71 37.69 197.89 n3 Unit 3 9,157 576.17 732.59 13.60 0 107.87 79.28 3.05 13.32 36.63 283.88 n3

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals

SRCNAM SO2 SO4 NOX HNO3 NO3 SOA PMF PMC EC NGS1 487.75 12.79 703.58 0 0 35.18 63.86 86.89 2.45 NGS2 526.92 13.71 753.88 0 0 37.69 55.27 75.20 2.12 NGS3 576.17 13.32 732.59 0 0 36.63 79.28 107.87 3.05**Control Option 4: SCR Units 1 - 3; air preheater penetration 0.9** Filterable PM10 Condensable PM10 (CPM) Filterable PM Max Heat Input SO2 NOx H2SO4 NH3 PM coarse PM fine soil PM fine

EC inorganic

(SO4) organic

(SOA) Max Stack

Test MMBtu/hr lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu

Unit 1 8,795 0.06 0.05 0.0034 0 0.010 0.007 0.00028 0.0033 0.0040 0.026

Unit 2 9,423 0.06 0.05 0.0034 0 0.008 0.006 0.00023 0.0033 0.0040 0.021

Unit 3 9,157 0.06 0.05 0.0034 0 0.012 0.009 0.00033 0.0033 0.0040 0.031

Filterable PM10 Condensable PM10 (CPM) Filterable PM 

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals Max Heat Input SO2 NOx H2SO4 NH3 PM coarse PM fine soil PM fine

EC inorganic

(SO4) organic

(SOA) Max Stack

Test MMBtu/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr scen SRCNAM SO2 SO4 NOX HNO3 NO3 SOA PMF PMC EC Unit 1 8,795 487.75 439.74 30.06 0 86.89 63.86 2.45 29.44 35.18 228.66 n4 NGS1 487.75 29.44 439.74 0 0 35.18 63.86 86.89 2.45 Unit 2 9,423 526.92 471.17 32.21 0 75.20 55.27 2.12 31.54 37.69 197.89 n4 NGS2 526.92 31.54 471.17 0 0 37.69 55.27 75.20 2.12 Unit 3 9,157 576.17 457.87 31.30 0 107.87 79.28 3.05 30.65 36.63 283.88 n4 NGS3 576.17 30.65 457.87 0 0 36.63 79.28 107.87 3.05

09000064811c2027 n4 SCRp9 1/18/2013**EPA revisions to values used in A** **NPRM**

MMBtu/day MMBtu/hr % ton/day lb/hr

Navajo 1 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, LNB, SOFA, **SCR** , hot side ESP, wet FGD 211,074 8,795 0.593 5.85 487.75

Navajo 2 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, LNB, SOFA, hot side ESP, wet FGD 226,163 9,423 0.593 6.32 526.92

Navajo 3 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, LNB, SOFA, hot side ESP, wet FGD 219,778 9,157 0.593 6.91 576.17

Unit conversion for ammonia slip from ppmvd to lb/hr (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiam Battye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (h) Total condensable PM10 is the sum of H2SO4 and organic condensable PM10 emissions. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. EPRI (2008) Eqn 4-2b indicates that 95% of fuel sulfur is converted to SO2. (j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998. (k) Ammonia slip is 0.75 ppmvd at 6% O2 for SCR. (l) Ammonia is assumed to react with SO4 to form ammonium sulfate per EPRI 2008 if the molecules of NH3 are at least twice those of H2SO4; otherwise, ammonium bisulfate is formed. 

### (a) Maximum daily

**24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02.** (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or malfunction. (d) Maximum daily

/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. (e) Maximum of 6 stack test results for the 2001 to 2006 period. (f) For a dry

bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998.



### Control Option 5: Low**NOx Burners, Separated Overfire A ir, and Selective Cataly** **tic Reduction (Unit 1 only ) _ EPA**  **modified to use Ultra-low activity**  **cataly st and NOx emssions of 0.05 lb/MMBtu** 

Facility Unit Description Maximum Heat Input (a) Maximum Sulfur Content (b) Maximum SO2 EmissionsNH3 0.75 ppm vd at 6% O2 0.00045 lb/MMBtu unit 1 3.99 lb/hr unit 2 4.27 lb/hr unit 3 4.15 lb/hr

(6) The 0.63 ESP penetration is applied to H2SO4 before the ammonia reaction, which mainly occurs in the lower temperatures of the air preheater. (5) Ammonia slip calculation only affects split between H2SO4 and ammonium sulfate/bisulfate. Since in this case there is no ammonia slip, and controls are assumed to affect all these the same way, the split is irrelevant, and only total am ount of SO4 matters for modeling. (4) 0.67% SO2 to SO3 conversion efficiency : Three layers give 0.5% conversion; may not have 4th till 3rd year, but conservatively assume all in four place at start. 1 - (1 - 0.005)^(3/4) or 0.005*4/3 are both about 0.0067 = 0.67% (3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater (instead of AECOM's value of 0.9) for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for PRB coal (strongly alkaline coal) 

### EPA revisions to Values used in ANPRM (3-7-11) (1) set HCl and HF to zero (2) in sulfuric acid calculation, revised penetration factor for hot-side ESP from 1 (used in ANPRM) to 0.63.lb/MMBtu % reduction ton/day lb/hr lb/MMBtu lb/MMBtu (e) lb/hr lb/hr

0.055 90% 5.28 439.74 0.050 0.026 228.66 153.20 (f)

0.056 46% 27.14 2,261.63 0.240 0.021 197.89 132.59 (f)

0.063 47% 26.37 2,197.78 0.240 0.031 283.88 190.20 (f)

(g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x (j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998. (l) Ammonia is assumed to react with SO4 to form ammonium sulfate per EPRI 2008 if the molecules of NH3 are at least twice those of H2SO4; otherwise, ammonium bisulfate is formed. 

### (a) Maximum daily

**24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02.** (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown (d) Maximum daily

/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. (f) For a dry

bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. total Maximum Filterable PM Em issions 

## Maximum Emissions Including Speciated PM **10**

## Emissions

**Navajo Units 1, 2, and 3 Control Option 5: Low** **NOx Burners, Separated Overfire A ir, and Selective Cataly** **tic Reduction (Unit 1 only ) _ EPA**  **modified to use Ultra-low activity**  **cataly st and NOx emssions of 0.05 lb/MMBtu** 

Maximum SO2 Emissions (c) Maximum NOx Emissions (d)(6) The 0.63 ESP penetration is applied to H2SO4 before the ammonia reaction, which mainly occurs in the lower temperatures of the air preheater. (5) Ammonia slip calculation only affects split between H2SO4 and ammonium sulfate/bisulfate. Since in this case there is no ammonia slip, and controls are assumed to affect all these the same way, the split is irrelevant, and only total am ount of SO4 matters for modeling. (4) 0.67% SO2 to SO3 conversion efficiency : Three layers give 0.5% conversion; may not have 4th till 3rd year, but conservatively assume all in four place at start. 1 - (1 - 0.005)^(3/4) or 0.005*4/3 are both about 0.0067 = 0.67% (3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater (instead of AECOM's value of 0.9) for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value offine total fine soil EC

lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr

86.89 (f) 66.31 (f) 63.9 (g) 2.45 (g) 51.88 (h) 16.70 (i) 35.18 (j) 71.06

75.20 (f) 57.39 (f) 55.3 (g) 2.12 (g) 40.24 (h) 2.54 (i) 37.69 (j) 10.82

107.87 (f) 82.33 (f) 79.3 (g) 3.05 (g) 39.10 (h) 2.47 (i) 36.63 (j) 10.52

(g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiam Battye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 

### (a) Maximum daily

**24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02.** (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown coarse Fine total H2SO4 organic Filterable PM 10 Condensable PM 10 H2SO4 before NH3 interaction, after ESP 

### Control Option 5: Low**NOx Burners, Separated Overfire A ir, and Selective Cataly** **tic Reduction (Unit 1 only ) _ EPA**  **modified to use Ultra-low activity**  **cataly st and NOx emssions of 0.05 lb/MMBtu** (5) Ammonia slip calculation only affects split between H2SO4 and ammonium sulfate/bisulfate. Since in this case there is no ammonia slip, and controls are assumed to affect all these the same way, the split is irrelevant, and only total am ount of SO4 matters for modeling. (4) 0.67% SO2 to SO3 conversion efficiency : Three layers give 0.5% conversion; may not have 4th till 3rd year, but conservatively assume all in four place at start. 1 - (1 - 0.005)^(3/4) or 0.005*4/3 are both about 0.0067 = 0.67% (3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater (instead of AECOM's value of 0.9) for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value oflb/hr lb m ole/hr lb m ole/hr mo le ratio lb m ole/hr lb m ole/hr lb m ole/hr lb m ole/hr

3.99 (k) 0.234 0.724 0.323 0.490 0.234 0.000 0.000

0 0 0.026

0 0 0.025

Am mo nia slip and reaction with sulfuric acid, for Net ammonia slip and Modeling SO4

[NH3] / [H2SO4] ratio [H2SO4]

after reaction [AbS] or

[NH4HSO4] after reaction [AS] or

[(NH4)2SO 4] after reaction [NH3] after

reaction [H2SO4] NH3 Slip [NH3]H2SO4 HCl HF HCl + HF HCl+HF+ Pm fine lb/hr lb/hr lb/hr lb/hr lb/m mbtu lb/m mbtu lb/Mm btu lb/hr new PM fine

**0.00** 17.64 **16.35** 204.74 0.0019 0 0 0 63.86

**0** 0.60 **2.49** 172.77 0.0003 0 0 0 55.27

**0** 0.58 **2.42** 229.25 0.0003 0 0 0 79.28 Am mo nia slip and reaction with sulfuric acid, for Net ammonia slip and Modeling SO4 Net NH3 after reaction & WF GD Total PM10

H2SO4 + AbS + AS post-control Total

Effective SO4 for modeling

### For copying to Word version of tables Highlight num bers portion of table here, copy; then in W ord, highlight num bers section of its table, paste

**Control Option 5: SCR Unit 1, LNB on Units 2 & 3** Filterable PM10

Max Heat Input SO2 NOx H2SO4 NH3 PM coarse PM fine soil MMBtu/hr lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu

Unit 1 8,795 0.06 0.05 0.0019 0 0.010 0.007

Unit 2 9,423 0.06 0.24 0.0003 0 0.008 0.006

Unit 3 9,157 0.06 0.24 0.0003 0 0.012 0.009

Filterable PM10 Max Heat Input SO2 NOx H2SO4 NH3 PM coarse PM fine soil MMBtu/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr Unit 1 8,795 487.75 439.74 16.70 0 86.89 63.86 Unit 2 9,423 526.92 2261.63 2.54 0 75.20 55.27 Unit 3 9,157 576.17 2197.78 2.47 0 107.87 79.28 4899.15Highlight num bers portion of table here, copy; then in W ord, highlight num bers section of its table, paste

Condensable PM10 (CPM) Filterable PM PM fine EC inorganic

(SO4) organic

(SOA) Max Stack

Test lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu

0.00028 0.0019 0.0040 0.026

0.00023 0.0003 0.0040 0.021

0.00033 0.0003 0.0040 0.031

Condensable PM10 (CPM) Filterable PM 

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals PM fine EC inorganic

(SO4) organic

(SOA) Max Stack

Test lb/hr lb/hr lb/hr lb/hr scen SRCNAM SO2 SO4 NOX 2.45 16.35 35.18 228.66 n5 NGS1 487.75 16.35 439.74 2.12 2.49 37.69 197.89 n5 NGS2 526.92 2.49 2261.63 3.05 2.42 36.63 283.88 n5 NGS3 576.17 2.42 2197.78

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals

HNO3 NO3 SOA PMF PMC EC 0 0 35.18 63.86 86.89 2.45 0 0 37.69 55.27 75.20 2.12 0 0 36.63 79.28 107.87 3.05**EPA revisions to values used in A** **NPRM**

MMBtu/day MMBtu/hr % ton/day lb/hr

Navajo 1 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, LNB, SOFA, **SCR** , hot side ESP, wet FGD 211,074 8,795 0.593 5.85 487.75

Navajo 2 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, LNB, SOFA, hot side ESP, wet FGD 226,163 9,423 0.593 6.32 526.92

Navajo 3 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, LNB, SOFA, **SCR** , hot side ESP, wet FGD 219,778 9,157 0.593 6.91 576.17

Unit conversion for ammonia slip from ppmvd to lb/hr NH3 0.75 ppm vd at 6% O2



### Control Option 6: Low**NOx Burners, Separated Overfire A ir and Selective Cataly** **tic Reduction (Units 1 & 3 only ); NOx emissions of 0.05 lb/MMBtu** 

(l) Ammonia is assumed to react with SO4 to form ammonium sulfate per EPRI 2008 if the molecules of NH3 are at least twice those of H2SO4; otherwise, ammonium bisulfate is formed. (f) For a dry

bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiam Battye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (h) Total condensable PM10 is the sum of H2SO4 and organic condensable PM10 emissions. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. EPRI (2008) Eqn 4-2b indicates that 95% of fuel sulfur is converted to SO2. (j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998. (k) Ammonia slip is 0.75 ppmvd at 6% O2 for SCR. 

### ** Below**are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately** (a) Maximum daily

24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02. (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or malfunction. (d) Maximum daily

/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. (e) Maximum of 6 stack test results for the 2001 to 2006 period. Facility Unit Description Maximum Heat Input (a) Maximum Sulfur Content (b) Maximum SO2 Emissions0.00045 lb/MMBtu unit 1 3.99 lb/hr unit 2 4.27 lb/hr unit 3 4.15 lb/hr

(6) The 0.63 ESP penetration is applied to H2SO4 before the ammonia reaction, which mainly occurs in the lower temperatures of the air preheater. SCR conversion of SO2 to SO3 99.50% = fraction SO2 remaining after 3 layers, corresponding to 0.5% conversion layers conversion

1 0.17% 2 0.33% 3 0.50% 4 0.67%

Penetration factors H2SO4 AbS and AS PM, general p % ctrl p % ctrl p hot-side ESP 0.63 37% 0.01 99% 0.01 Air Preheater 0.50 50% 0.75 25% Wet FGD (scrubber) 0.47 53% 0.50 50% EPRI H2SO4 doc EPRI NH3 doc (5) Ammonia slip calculation only affects split between H2SO4 and ammonium sulfate/bisulfate. Since in this case there is no ammonia slip, and controls are assumed to affect all these the same way, the split is irrelevant, and only total am ount of SO4 matters for modeling. (Since all SO4 forms are assumed to be affected the same way, the SO4 for modeling can also be calculated directly from H2SO4 * 96.06/98.08.) 

### EPA revisions to Values used in ANPRM (3-7-11) (1) set HCl and HF to zero (2) in sulfuric acid calculation, revised penetration factor for hot-side ESP from 1 (used in ANPRM) to 0.63. (3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for PRB coal (strongly

alkaline coal) (4) 0.67% SO2 to SO3 conversion efficiency : Three layers give 0.5% conversion; may not have 4th till 3rd year, but conservatively assume all in four place at start. 1 - (1 - 0.005)^(3/4) or 0.005*4/3 are both about 0.0067 = 0.67%, see belowlb/MMBtu % reduction ton/day lb/hr lb/MMBtu lb/MMBtu (e) lb/hr lb/hr

0.055 90% 5.28 439.74 0.050 0.026 228.66 153.20 (f)

0.056 46% 27.14 2,261.63 0.240 0.021 197.89 132.59 (f)

0.063 89% 5.49 457.87 0.050 0.031 283.88 190.20 (f)

Method 19 (SO2 removal efficiency) formula, Eq. 19-1: 

### Control Option 6: Low**NOx Burners, Separated Overfire A ir and Selective Cataly** **tic Reduction (Units 1 & 3 only ); NOx emissions of 0.05 lb/MMBtu** 

(l) Ammonia is assumed to react with SO4 to form ammonium sulfate per EPRI 2008 if the molecules of NH3 are at least twice those of H2SO4; otherwise, ammonium bisulfate is formed. (f) For a dry

bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x (j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998. 

### ** Below**are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately** (a) Maximum daily

24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02. (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or malfunction. (d) Maximum daily

/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. total Maximum Filterable PM Em issions 

## Maximum Emissions Including Speciated PM **10**

## Emissions

**Navajo Units 1, 2, and 3**

Maximum SO2 Emissions (c) Maximum NOx Emissions (d)E = Cd*Fd*20.9/(20.9 - %O2d) Atm osphere is 20.9% oxygen

Cd = Pollutant concentration, dry basis Am mo nia M.W . is 17 lb/lb.mol Fd = volum es of combustion components per unit of heat content 385 ft3/lb-mol = volume of 1 ft3 of gas at STP %O2d = Concentration of oxygen on a dry basis, percent. Table 19-2 gives F factor for bituminous coal as Fd = 9780 sdcf/10^6 Btu

(6) The 0.63 ESP penetration is applied to H2SO4 before the ammonia reaction, which mainly occurs in the lower temperatures of the air preheater. = fraction SO2 remaining after 3 layers, corresponding to 0.5% conversion

% ctrl 99% (5) Ammonia slip calculation only affects split between H2SO4 and ammonium sulfate/bisulfate. Since in this case there is no ammonia slip, and controls are assumed to affect all these the same way, the split is irrelevant, and only total am ount of SO4 matters for modeling. (Since all SO4 forms are assumed to be affected the same way, the SO4 for modeling can also be calculated directly from H2SO4 * 96.06/98.08.) (3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for (4) 0.67% SO2 to SO3 conversion efficiency : Three layers give 0.5% conversion; may not have 4th till 3rd year, but conservatively assume all in four place at start. 1 - (1 - 0.005)^(3/4) or 0.005*4/3 are both about 0.0067 = 0.67%, see belowfine total fine soil EC

lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr

86.89 (f) 66.31 (f) 63.9 (g) 2.45 (g) 51.88 (h) 16.70 (i) 35.18 (j) 71.06

75.20 (f) 57.39 (f) 55.3 (g) 2.12 (g) 40.24 (h) 2.54 (i) 37.69 (j) 10.82

107.87 (f) 82.33 (f) 79.3 (g) 3.05 (g) 54.02 (h) 17.39 (i) 36.63 (j) 73.99 

### Control Option 6: Low**NOx Burners, Separated Overfire A ir and Selective Cataly** **tic Reduction (Units 1 & 3 only ); NOx emissions of 0.05 lb/MMBtu** 

(g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiam Battye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or malfunction. coarse Fine total H2SO4 organic Filterable PM 10 Condensable PM 10 H2SO4 before NH3 interaction, after ESPAtm osphere is 20.9% oxygen Am mo nia M.W . is 17 lb/lb.mol 385 ft3/lb-mol = volume of 1 ft3 of gas at STP

(5) Ammonia slip calculation only affects split between H2SO4 and ammonium sulfate/bisulfate. Since in this case there is no ammonia slip, and controls are assumed to affect all these the same way, the split is irrelevant, and only total am ount of SO4 matters for modeling. (Since all SO4 forms are (3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for (4) 0.67% SO2 to SO3 conversion efficiency : Three layers give 0.5% conversion; may not have 4th till 3rd year, but conservatively assume all in four place at start. 1 - (1 - 0.005)^(3/4) or 0.005*4/3 are both about 0.0067 = 0.67%, see belowlb/hr lb m ole/hr lb m ole/hr mo le ratio lb m ole/hr lb m ole/hr lb m ole/hr lb m ole/hr

3.99 (k) 0.234 0.724 0.323 0.490 0.234 0.000 0.000

0 0 0.026

4.15 (k) 0.244 0.754 0.323 0.510 0.244 0.000 0.000 [H2SO4] [NH3] /

[H2SO4] ratio [H2SO4]

after reaction [AbS] or

[NH4HSO4] after reaction [AS] or

[(NH4)2SO 4] after reaction [NH3] after

reaction NH3 Slip [NH3]

Am mo nia slip and reaction with sulfuric acid, for Net ammonia slip and Modeling SO4H2SO4 HCl HF HCl + HF HCl+HF+ Pm fine lb/hr lb/hr lb/hr lb/hr lb/m mbtu lb/m mbtu lb/Mm btu lb/hr new PM fine

**0.00** 17.64 **16.35 206.02**  **0.0019** 0 0 0 63.86

**0** 0.60 **2.49** 172.77 **0.0003** 0 0 0 55.27

**0.00** 18.36 **17.03** 245.192 **0.0019** 0 0 0 79.28 Net NH3 after reaction & WF GD H2SO4 +

AbS + AS post-control Total

Effective SO4 for modeling Total PM10 Am mo nia slip and reaction with sulfuric acid, for Net ammonia slip and Modeling SO4

### For copying to Word version of tables Highlight num bers portion of table here, copy; then goto W ord, highlight num bers section of its table, paste

**Control Option 6: SCR Units 1 and 3, LNB on Unit 2** Filterable PM10

Max Heat Input SO2 NOx H2SO4 NH3 PM coarse PM fine soil MMBtu/hr lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu

Unit 1 8,795 0.06 0.05 0.0019 0 0.010 0.007

Unit 2 9,423 0.06 0.24 0.0003 0 0.008 0.006

Unit 3 9,157 0.06 0.05 0.0019 0 0.012 0.009

Filterable PM10 Max Heat Input SO2 NOx H2SO4 NH3 PM coarse PM fine soil MMBtu/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr Unit 1 8,795 487.75 439.74 16.70 0 86.89 63.86 Unit 2 9,423 526.92 2261.63 2.54 0 75.20 55.27 Unit 3 9,157 576.17 457.87 17.39 0 107.87 79.28 3159.24Highlight num bers portion of table here, copy; then goto W ord, highlight num bers section of its table, paste

Condensable PM10 (CPM) Filterable PM PM fine EC inorganic

(SO4) organic

(SOA) Max Stack

Test lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu

0.00028 0.0019 0.0040 0.026

0.00023 0.0003 0.0040 0.021

0.00033 0.0019 0.0040 0.031

Condensable PM10 (CPM) 

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals PM fine EC inorganic

(SO4) organic

(SOA) Max Stack

Test lb/hr lb/hr lb/hr lb/hr scen SRCNAM SO2 SO4 NOX 2.45 16.35 35.18 228.66 n6 NGS1 487.75 16.35 439.74 2.12 2.49 37.69 197.89 n6 NGS2 526.92 2.49 2261.63 3.05 17.03 36.63 283.88 n6 NGS3 576.17 17.03 457.87

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals

HNO3 NO3 SOA PMF PMC EC 0 0 35.18 63.86 86.89 2.45 0 0 37.69 55.27 75.20 2.12 0 0 36.63 79.28 107.87 3.05

### Control Option 7: Low**NOx Burners, Separated Overfire A ir, and Selective Cataly** **tic Reduction (Units 1, 2 & 3), SCR after ESP _ EPA modified to use Ultra-low** **activity cataly** **st and NOx limit 0.05 lb/MMBtu**

MMBtu/day MMBtu/hr % ton/day lb/hr

Navajo 1 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, LNB, SOFA, hot side ESP, **SCR** , wet FGD 211,074 8,795 0.593 5.85 487.75

Navajo 2 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, LNB, SOFA, hot side ESP, **SCR** , wet FGD 226,163 9,423 0.593 6.32 526.92

Navajo 3 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, LNB, SOFA, hot side ESP, **SCR** , wet FGD 219,778 9,157 0.593 6.91 576.17

Unit conversion for ammonia slip from ppmvd to lb/hr NH3 0.75 ppm vd at 6% O2 (l) Ammonia is assumed to react with SO4 to form ammonium sulfate per EPRI 2008 if the molecules of NH3 are at least twice those of H2SO4; otherwise, ammonium bisulfate is formed. (f) For a dry

bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiam Battye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (h) Total condensable PM10 is the sum of H2SO4 and organic condensable PM10 emissions. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. EPRI (2008) Eqn 4-2b indicates that 95% of fuel sulfur is converted to SO2. (j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998. (k) Ammonia slip is 0.75 ppmvd at 6% O2 for SCR. 

### ** Below**are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately** (a) Maximum daily

24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02. (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or malfunction. (d) Maximum daily

/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. (e) Maximum of 6 stack test results for the 2001 to 2006 period. Facility Unit Description Maximum Heat Input (a) Maximum Sulfur Content (b) Maximum SO2 Emissions0.00045 lb/MMBtu unit 1 3.99 lb/hr unit 2 4.27 lb/hr unit 3 4.15 lb/hr

(6) The 0.63 ESP penetration is applied to fuel S oxidation H2SO4 (but not to catalyst oxidation, which occurs after the ESP) before the ammonia reaction, which mainly occurs in the lower temperatures of the air preheater. SCR conversion of SO2 to SO3 99.50% = fraction SO2 remaining after 3 layers, corresponding to 0.5% conversion layers conversion

1 0.17% 2 0.33% 3 0.50% 4 0.67%

Penetration factors H2SO4 AbS and AS PM, general p % ctrl p % ctrl p hot-side ESP 0.63 37% 0.01 99% 0.01 Air Preheater 0.50 50% 0.75 25% Wet FGD (scrubber) 0.47 53% 0.50 50% EPRI H2SO4 doc EPRI NH3 doc (5) Ammonia slip calculation only affects split between H2SO4 and ammonium sulfate/bisulfate. Since in this case there is no ammonia slip, and controls are assumed to affect all these the same way, the split is irrelevant, and only total am ount of SO4 matters for modeling. (Since all SO4 forms are assumed to be affected the same way, the SO4 for modeling can also be calculated directly from H2SO4 * 96.06/98.08.) 

### EPA revisions to Values used in ANPRM (3-7-11) (1) set HCl and HF to zero (2) in sulfuric acid calculation, revised penetration factor for hot-side ESP from 1 (used in ANPRM) to 0.63. (3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for PRB coal (strongly

alkaline coal) (4) 0.67% SO2 to SO3 conversion efficiency : Three layers give 0.5% conversion; may not have 4th till 3rd year, but conservatively assume all in four place at start. 1 - (1 - 0.005)^(3/4) or 0.005*4/3 are both about 0.0067 = 0.67%, see below

### Control Option 7: Low**NOx Burners, Separated Overfire A ir, and Selective Cataly** **tic Reduction (Units 1, 2 & 3), SCR after ESP _ EPA modified to use Ultra-low** **activity cataly** **st and NOx limit 0.05 lb/MMBtu**

lb/MMBtu % reduction ton/day lb/hr lb/MMBtu lb/MMBtu (e) lb/hr lb/hr

0.055 90% 5.28 439.74 0.050 0.026 228.66 153.20 (f)

0.056 89% 5.65 471.17 0.050 0.021 197.89 132.59 (f)

0.063 89% 5.49 457.87 0.050 0.031 283.88 190.20 (f)

Method 19 (SO2 removal efficiency) formula, Eq. 19-1: (l) Ammonia is assumed to react with SO4 to form ammonium sulfate per EPRI 2008 if the molecules of NH3 are at least twice those of H2SO4; otherwise, ammonium bisulfate is formed. (f) For a dry

bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x (j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998. 

### ** Below**are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately** (a) Maximum daily

24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02. (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or malfunction. (d) Maximum daily

/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. total Maximum Filterable PM Em issions 

## Maximum Emissions Including Speciated PM **10**

## Emissions

**Navajo Units 1, 2, and 3**

Maximum SO2 Emissions (c) Maximum NOx Emissions (d)E = Cd*Fd*20.9/(20.9 - %O2d) Atm osphere is 20.9% oxygen

Cd = Pollutant concentration, dry basis Am mo nia M.W . is 17 lb/lb.mol Fd = volum es of combustion components per unit of heat content 385 ft3/lb-mol = volume of 1 ft3 of gas at STP %O2d = Concentration of oxygen on a dry basis, percent. Table 19-2 gives F factor for bituminous coal as Fd = 9780 sdcf/10^6 Btu

(6) The 0.63 ESP penetration is applied to fuel S oxidation H2SO4 (but not to catalyst oxidation, which occurs after the ESP) before the ammonia reaction, which mainly occurs in the lower temperatures of the air preheater. = fraction SO2 remaining after 3 layers, corresponding to 0.5% conversion

% ctrl 99% (5) Ammonia slip calculation only affects split between H2SO4 and ammonium sulfate/bisulfate. Since in this case there is no ammonia slip, and controls are assumed to affect all these the same way, the split is irrelevant, and only total am ount of SO4 matters for modeling. (Since all SO4 forms are assumed to be affected the same way, the SO4 for modeling can also be calculated directly from H2SO4 * 96.06/98.08.) (3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for (4) 0.67% SO2 to SO3 conversion efficiency : Three layers give 0.5% conversion; may not have 4th till 3rd year, but conservatively assume all in four place at start. 1 - (1 - 0.005)^(3/4) or 0.005*4/3 are both about 0.0067 = 0.67%, see below

### Control Option 7: Low**NOx Burners, Separated Overfire A ir, and Selective Cataly** **tic Reduction (Units 1, 2 & 3), SCR after ESP _ EPA modified to use Ultra-low** **activity cataly** **st and NOx limit 0.05 lb/MMBtu**

fine total fine soil EC lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr

86.89 (f) 66.31 (f) 63.9 (g) 2.45 (g) 60.29 (h) 25.11 (i) 35.18 (j) 106.86

75.20 (f) 57.39 (f) 55.3 (g) 2.12 (g) 64.60 (h) 26.91 (i) 37.69 (j) 114.49

107.87 (f) 82.33 (f) 79.3 (g) 3.05 (g) 62.78 (h) 26.15 (i) 36.63 (j) 111.26

(g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiam Battye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or malfunction. coarse Fine total H2SO4 organic Filterable PM 10 Condensable PM 10 H2SO4 before NH3 interaction, after ESPAtm osphere is 20.9% oxygen Am mo nia M.W . is 17 lb/lb.mol 385 ft3/lb-mol = volume of 1 ft3 of gas at STP

(6) The 0.63 ESP penetration is applied to fuel S oxidation H2SO4 (but not to catalyst oxidation, which occurs after the ESP) before the ammonia reaction, which mainly occurs in the lower temperatures of the air preheater. (5) Ammonia slip calculation only affects split between H2SO4 and ammonium sulfate/bisulfate. Since in this case there is no ammonia slip, and controls are assumed to affect all these the same way, the split is irrelevant, and only total am ount of SO4 matters for modeling. (Since all SO4 forms are (3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for (4) 0.67% SO2 to SO3 conversion efficiency : Three layers give 0.5% conversion; may not have 4th till 3rd year, but conservatively assume all in four place at start. 1 - (1 - 0.005)^(3/4) or 0.005*4/3 are both about 0.0067 = 0.67%, see belowlb/hr lb m ole/hr lb m ole/hr mo le ratio lb m ole/hr lb m ole/hr lb m ole/hr lb m ole/hr

3.99 (k) 0.234 1.089 0.215 0.855 0.234 0.000 0.000

4.27 (k) 0.251 1.167 0.215 0.916 0.251 0.000 0.000

4.15 (k) 0.244 1.134 0.215 0.890 0.244 0.000 0.000 [H2SO4] [NH3] /

[H2SO4] ratio [H2SO4]

after reaction [AbS] or

[NH4HSO4] after reaction [AS] or

[(NH4)2SO 4] after reaction [NH3] after

reaction NH3 Slip [NH3]

Am mo nia slip and reaction with sulfuric acid, for Net ammonia slip and Modeling SO4H2SO4 HCl HF HCl + HF HCl+HF+ Pm fine lb/hr lb/hr lb/hr lb/hr lb/m mbtu lb/m mbtu lb/Mm btu lb/hr new PM fine

**0.00** 26.05 **24.59 214.43**  **0.0029** 0 0 0 63.86

**0.00** 27.91 **26.35** 198.193 **0.0029** 0 0 0 55.27

**0.00** 27.12 **25.61** 253.952 **0.0029** 0 0 0 79.28 Net NH3 after reaction & WF GD H2SO4 +

AbS + AS post-control Total

Effective SO4 for modeling Total PM10 Am mo nia slip and reaction with sulfuric acid, for Net ammonia slip and Modeling SO4

### For copying to Word version of tables Highlight num bers portion of table here, copy; then goto W ord, highlight num bers section of its table, paste

**Control Option 7: SCR Units 1 - 3, after ESP** Filterable PM10

Max Heat Input SO2 NOx H2SO4 NH3 PM coarse PM fine soil MMBtu/hr lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu

Unit 1 8,795 0.06 0.05 0.0029 0 0.010 0.007

Unit 2 9,423 0.06 0.05 0.0029 0 0.008 0.006

Unit 3 9,157 0.06 0.05 0.0029 0 0.012 0.009

Filterable PM10 Max Heat Input SO2 NOx H2SO4 NH3 PM coarse PM fine soil MMBtu/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr Unit 1 8,795 487.75 439.74 25.11 0 86.89 63.86 Unit 2 9,423 526.92 471.17 16.70 0 75.20 55.27 Unit 3 9,157 576.17 457.87 16.70 0 107.87 79.28 1368.78Highlight num bers portion of table here, copy; then goto W ord, highlight num bers section of its table, paste

Condensable PM10 (CPM) Filterable PM PM fine EC inorganic

(SO4) organic

(SOA) Max Stack

Test lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu

0.00028 0.0028 0.0040 0.026

0.00023 0.0028 0.0040 0.021

0.00033 0.0028 0.0040 0.031

Condensable PM10 (CPM) 

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals PM fine EC inorganic

(SO4) organic

(SOA) Max Stack

Test lb/hr lb/hr lb/hr lb/hr scen SRCNAM SO2 SO4 NOX 2.45 24.59 35.18 228.66 n7 NGS1 487.75 24.59 439.74 2.12 26.35 37.69 197.89 n7 NGS2 526.92 26.35 471.17 3.05 25.61 36.63 283.88 n7 NGS3 576.17 25.61 457.87

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals

HNO3 NO3 SOA PMF PMC EC 0 0 35.18 63.86 86.89 2.45 0 0 37.69 55.27 75.20 2.12 0 0 36.63 79.28 107.87 3.05

### Control Option 8: Low**NOx Burners, Separated Overfire A ir, and Selective Non-Cataly** **tic Reduction at 0.18 lb/MMBtu (Units 1, 2 & 3)**

MMBtu/day MMBtu/hr % ton/day lb/hr

Navajo 1 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, LNB, SOFA, **SNCR** , hot side ESP, wet FGD 211,074 8,795 0.593 5.85 487.75

Navajo 2 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, LNB, SOFA, **SNCR** , hot side ESP, wet FGD 226,163 9,423 0.593 6.32 526.92

Navajo 3 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, LNB, SOFA, **SNCR** , hot side ESP, wet FGD 219,778 9,157 0.593 6.91 576.17

Unit conversion for ammonia slip from ppmvd to lb/hr NH3 5.00 ppm vd at 6% O2 (f) For a dry

bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. 

### ** Below**are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately** (a) Maximum daily

24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02. (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or malfunction. (d) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. Facility Unit Description Maximum Heat Input (a) Maximum Sulfur Content (b) Maximum SO2 Emissions

(e) Maximum of 6 stack test results for the 2001 to 2006 period. (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiam Battye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (h) Total condensible PM10 is the sum of H2SO4 and organic condensible PM10 emissions. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. EPRI (2008) Eqn 4-2b indicates that 95% of fuel sulfur is converted to SO2. (j) Organic condensible PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998.0.00302 lb/MMBtu unit 1 26.60 lb/hr unit 2 28.50 lb/hr unit 3 27.69 lb/hr

Penetration factors H2SO4 AbS and AS PM, general p % ctrl p % ctrl p hot-side ESP 0.63 37% 0.01 99% 0.01 Air Preheater 0.50 50% 0.75 25% Wet FGD (scrubber) 0.47 53% 0.50 50% EPRI H2SO4 doc EPRI NH3 doc (2) updated Ammonia-Sulfuric acid reaction to accommodate full range of NH3/H2SO4 ratios, and accounted for molecular weight of ammonium sulfate (AS) and bisulfate (AbS) (2) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for PRB coal (strongly

alkaline coal) 

### EPA **revisions** (1) in sulfuric acid calculation, revised penetration factor for hot-side ESP from 1 (used in ANPRM) to 0.63.

### Control Option 8: Low**NOx Burners, Separated Overfire A ir, and Selective Non-Cataly** **tic Reduction at 0.18 lb/MMBtu (Units 1, 2 & 3)**

lb/MMBtu % reduction ton/day lb/hr lb/MMBtu lb/MMBtu (e) lb/hr lb/hr

0.055 63% 19.00 1,583.06 0.180 0.026 228.66 153.20 (f)

0.056 60% 20.35 1,696.22 0.180 0.021 197.89 132.59 (f)

0.063 61% 19.78 1,648.34 0.180 0.031 283.88 190.20 (f)

Method 19 (SO2 removal efficiency) formula, Eq. 19-1: (f) For a dry

bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. 

### ** Below**are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately** (a) Maximum daily

24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02. (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown (d) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. 

## Maximum Emissions Including Speciated PM **10**

## Emissions

**Navajo Units 1, 2, and 3**

Maximum SO2 Emissions (c) Maximum NOx Emissions (d) Maximum Filterable PM Em issions total

(g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x (j) Organic condensible PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998.E = Cd*Fd*20.9/(20.9 - %O2d) Atm osphere is 20.9% oxygen

Cd = Pollutant concentration, dry basis Am mo nia M.W . is 17 lb/lb.mol Fd = volum es of combustion components per unit of heat content 385 ft3/lb-mol = volume of 1 ft3 of gas at STP %O2d = Concentration of oxygen on a dry basis, percent. Table 19-2 gives F factor for bituminous coal as Fd = 9780 sdcf/10^6 Btu

% ctrl 99% (2) updated Ammonia-Sulfuric acid reaction to accommodate full range of NH3/H2SO4 ratios, and accounted for molecular weight of ammonium sulfate (AS) and bisulfate (AbS) (2) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 forfine total fine soil EC

lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr

86.89 (f) 66.31 (f) 63.9 (g) 2.45 (g) 37.55 (h) 2.37 (i) 35.18 (j) 10.10

75.20 (f) 57.39 (f) 55.3 (g) 2.12 (g) 40.24 (h) 2.54 (i) 37.69 (j) 10.82

107.87 (f) 82.33 (f) 79.3 (g) 3.05 (g) 39.10 (h) 2.47 (i) 36.63 (j) 10.52

(c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown Filterable PM 10 Condensable PM 10 H2SO4 before NH3 interaction, after ESP organic coarse Fine total H2SO4

(g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiam Battye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input xAtm osphere is 20.9% oxygen Am mo nia M.W . is 17 lb/lb.mol 385 ft3/lb-mol = volume of 1 ft3 of gas at STP

(2) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 forlb/hr lb m ole/hr lb m ole/hr mo le ratio lb m ole/hr lb m ole/hr lb m ole/hr lb m ole/hr

26.60 (k) 1.562 0.103 15.167 0.000 0.000 0.103 1.356

28.50 (k) 1.673 0.110 15.167 0.000 0.000 0.110 1.453

27.69 (k) 1.626 0.107 15.167 0.000 0.000 0.107 1.412

Am mo nia slip and reaction with sulfuric acid, for Net ammonia slip and Modeling SO4 [AS] or [(NH4)2SO 4] after reaction NH3 Slip [NH3] [NH3] after reaction [H2SO4] [NH3] /

[H2SO4] ratio [H2SO4]

after reaction [AbS] or

[NH4HSO4] after reaction

### For copying to Word version of tables Highlight num bers portion of table here, copy; then in W ord, highlight num bers section of its table, paste

**Control Option 8: SNCR Units 1 - 3**

Max Heat Input SO2 NOx lb/hr lb/hr lb/hr lb/hr MMBtu/hr lb/MMBtu lb/MMBtu

2.309 3.197 2.32 191.58 Unit 1 8,795 0.06 0.18

2.474 3.426 2.490 173.708 Unit 2 9,423 0.06 0.18

2.404 3.329 2.420 230.158 Unit 3 9,157 0.06 0.18

Max Heat Input SO2 NOx MMBtu/hr lb/hr lb/hr Unit 1 8,795 487.75 1583.06 Unit 2 9,423 526.92 1696.22 Unit 3 9,157 576.17 1648.34 4927.61 Am mo nia slip and reaction with sulfuric acid, for Net ammonia slip and Modeling SO4 Net NH3 after reaction & WF GD H2SO4 +

AbS + AS post-control Total

Effective SO4 for modeling Total PM10

### For copying to Word version of tables Highlight num bers portion of table here, copy; then in W ord, highlight num bers section of its table, paste

Filterable PM10 Condensable PM10 (CPM) Filterable PM H2SO4 NH3 PM coarse PM fine soil PM fine

EC inorganic

(SO4) organic

(SOA) Max Stack

Test lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu

0.0003 0 0.010 0.000 0.00028 0.0003 0.0040 0.026

0.0003 0 0.008 0.000 0.00023 0.0003 0.0040 0.021

0.0003 0 0.012 0.000 0.00033 0.0003 0.0040 0.031

Filterable PM10 Condensable PM10 (CPM) Filterable PM 

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals H2SO4 NH3 PM coarse PM fine soil PM fine

EC inorganic

(SO4) organic

(SOA) Max Stack

Test lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr scen 2.37 0 86.89 0.03 2.45 2.32 35.18 228.66 n8 16.70 0 75.20 0.02 2.12 2.49 37.69 197.89 n8 16.70 0 107.87 0.03 3.05 2.42 36.63 283.88 n8

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals

SRCNAM SO2 SO4 NOX HNO3 NO3 SOA PMF PMC EC NGS1 487.75 2.32 1583.06 0 0 35.18 0.03 86.89 2.45 NGS2 526.92 2.49 1696.22 0 0 37.69 0.02 75.20 2.12 NGS3 576.17 2.42 1648.34 0 0 36.63 0.03 107.87 3.05

### Control Option 8: Low**NOx Burners, Separated Overfire A ir, and Selective Non-Cataly** **tic Reduction at 0.15 lb/MMBtu (Units 1, 2 & 3)**

MMBtu/day MMBtu/hr % ton/day lb/hr

Navajo 1 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, LNB, SOFA, **SNCR** , hot side ESP, wet FGD 211,074 8,795 0.593 5.85 487.75

Navajo 2 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, LNB, SOFA, **SNCR** , hot side ESP, wet FGD 226,163 9,423 0.593 6.32 526.92

Navajo 3 750 MW , PC,

bitum inous coal, dry bottom, tangential fired, LNB, SOFA, **SNCR** , hot side ESP, wet FGD 219,778 9,157 0.593 6.91 576.17

Unit conversion for ammonia slip from ppmvd to lb/hr NH3 5.00 ppm vd at 6% O2 (e) Maximum of 6 stack test results for the 2001 to 2006 period. (f) For a dry

bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiam Battye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (h) Total condensible PM10 is the sum of H2SO4 and organic condensible PM10 emissions. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. EPRI (2008) Eqn 4-2b indicates that 95% of fuel sulfur is converted to SO2. (j) Organic condensible PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998. 

### ** Below**are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately** (a) Maximum daily

24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02. (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or malfunction. (d) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. Facility Unit Description Maximum Heat Input (a) Maximum Sulfur Content (b) Maximum SO2 Emissions0.00302 lb/MMBtu unit 1 26.60 lb/hr unit 2 28.50 lb/hr unit 3 27.69 lb/hr

Penetration factors H2SO4 AbS and AS PM, general p % ctrl p % ctrl p hot-side ESP 0.63 37% 0.01 99% 0.01 Air Preheater 0.50 50% 0.75 25% Wet FGD (scrubber) 0.47 53% 0.50 50% EPRI H2SO4 doc EPRI NH3 doc 

### EPA **revisions** (1) in sulfuric acid calculation, revised penetration factor for hot-side ESP from 1 (used in ANPRM) to 0.63. (2) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for PRB coal (strongly

alkaline coal) (2) updated Ammonia-Sulfuric acid reaction to accommodate full range of NH3/H2SO4 ratios, and accounted for molecular weight of ammonium sulfate (AS) and bisulfate (AbS)

### Control Option 8: Low**NOx Burners, Separated Overfire A ir, and Selective Non-Cataly** **tic Reduction at 0.15 lb/MMBtu (Units 1, 2 & 3)**

lb/MMBtu % reduction ton/day lb/hr lb/MMBtu lb/MMBtu (e) lb/hr lb/hr

0.055 69% 15.83 1,319.21 0.150 0.026 228.66 153.20 (f)

0.056 66% 16.96 1,413.52 0.150 0.021 197.89 132.59 (f)

0.063 67% 16.48 1,373.61 0.150 0.031 283.88 190.20 (f)

Method 19 (SO2 removal efficiency) formula, Eq. 19-1: (f) For a dry

bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998. (g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x (j) Organic condensible PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998. 

### ** Below**are the Original footnotes from A ECOM - EPA**  **revisions to the footnotes/emission inputs are explained separately** (a) Maximum daily

24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02. (b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03. (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown (d) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01. total Maximum NOx Emissions (d) Maximum Filterable PM Em issions 

## Maximum Emissions Including Speciated PM **10**

## Emissions

**Navajo Units 1, 2, and 3**

Maximum SO2 Emissions (c)E = Cd*Fd*20.9/(20.9 - %O2d) Atm osphere is 20.9% oxygen

Cd = Pollutant concentration, dry basis Am mo nia M.W . is 17 lb/lb.mol Fd = volum es of combustion components per unit of heat content 385 ft3/lb-mol = volume of 1 ft3 of gas at STP %O2d = Concentration of oxygen on a dry basis, percent. Table 19-2 gives F factor for bituminous coal as Fd = 9780 sdcf/10^6 Btu

% ctrl 99% (2) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for (2) updated Ammonia-Sulfuric acid reaction to accommodate full range of NH3/H2SO4 ratios, and accounted for molecular weight of ammonium sulfate (AS) and bisulfate (AbS)fine total fine soil EC

lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr

86.89 (f) 66.31 (f) 63.9 (g) 2.45 (g) 37.55 (h) 2.37 (i) 35.18 (j) 10.10

75.20 (f) 57.39 (f) 55.3 (g) 2.12 (g) 40.24 (h) 2.54 (i) 37.69 (j) 10.82

107.87 (f) 82.33 (f) 79.3 (g) 3.05 (g) 39.10 (h) 2.47 (i) 36.63 (j) 10.52

(g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, W illiam Battye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002. (i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x (c) Maximum daily

24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown coarse Fine total H2SO4 organic Filterable PM 10 Condensable PM 10 H2SO4 before NH3 interaction, after ESPAtm osphere is 20.9% oxygen Am mo nia M.W . is 17 lb/lb.mol 385 ft3/lb-mol = volume of 1 ft3 of gas at STP

(2) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 forlb/hr lb m ole/hr lb m ole/hr mo le ratio lb m ole/hr lb m ole/hr lb m ole/hr lb m ole/hr

26.60 (k) 1.562 0.103 15.167 0.000 0.000 0.103 1.356

28.50 (k) 1.673 0.110 15.167 0.000 0.000 0.110 1.453

27.69 (k) 1.626 0.107 15.167 0.000 0.000 0.107 1.412

Am mo nia slip and reaction with sulfuric acid, for Net ammonia slip and Modeling SO4

[NH3] / [H2SO4] ratio [NH3] [H2SO4] after reaction [AbS] or

[NH4HSO4] after reaction [AS] or

[(NH4)2SO 4] after reaction [NH3] after

reaction NH3 Slip [H2SO4]

### For copying to Word version of tables Highlight num bers portion of table here, copy; then in W ord, highlight num bers section of its table, paste

**Control Option 8: SNCR Units 1 - 3**

Max Heat Input SO2 NOx lb/hr lb/hr lb/hr lb/hr MMBtu/hr lb/MMBtu lb/MMBtu

2.309 3.197 **2.32 191.58**  Unit 1 8,795 0.06 0.15

2.474 3.426 **2.490 173.708**  Unit 2 9,423 0.06 0.15

2.404 3.329 **2.420 230.158**  Unit 3 9,157 0.06 0.15

Max Heat Input SO2 NOx MMBtu/hr lb/hr lb/hr Unit 1 8,795 487.75 1319.21 Unit 2 9,423 526.92 1413.52 Unit 3 9,157 576.17 1373.61 4106.34 Am mo nia slip and reaction with sulfuric acid, for Net ammonia slip and Modeling SO4 H2SO4 + AbS + AS post-control Total

Effective SO4 for modeling Total PM10 Net NH3 after reaction & WF GD

### For copying to Word version of tables Highlight num bers portion of table here, copy; then in W ord, highlight num bers section of its table, paste

Filterable PM10 Condensable PM10 (CPM) Filterable PM H2SO4 NH3 PM coarse PM fine soil PM fine

EC inorganic

(SO4) organic

(SOA) Max Stack

Test lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu

0.0003 0 0.010 0.000 0.00028 0.0003 0.0040 0.026

0.0003 0 0.008 0.000 0.00023 0.0003 0.0040 0.021

0.0003 0 0.012 0.000 0.00033 0.0003 0.0040 0.031

Filterable PM10 Condensable PM10 (CPM) Filterable PM 

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals H2SO4 NH3 PM coarse PM fine soil PM fine

EC inorganic

(SO4) organic

(SOA) Max Stack

Test lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr scen 2.37 0 86.89 0.03 2.45 2.32 35.18 228.66 n9 16.70 0 75.20 0.02 2.12 2.49 37.69 197.89 n9 16.70 0 107.87 0.03 3.05 2.42 36.63 283.88 n9

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals

SRCNAM SO2 SO4 NOX HNO3 NO3 SOA PMF PMC EC NGS1 487.75 2.32 1319.21 0 0 35.18 0.03 86.89 2.45 NGS2 526.92 2.49 1413.52 0 0 37.69 0.02 75.20 2.12 NGS3 576.17 2.42 1373.61 0 0 36.63 0.03 107.87 3.05**Parameter Unit 1**  **Unit 2 Unit 3**  **Parameter Unit 1**  **Unit 2 Unit 3** 

Height, ft 775 775 775 Height, m 236.2 236.2 236.2 Diam eter, ft 24.5 24.5 24.50 Diam eter, m 7.47 7.47 7.47 Flow, acfm 2,497,502 2,497,502 2,497,502 Flow, m 3/s 1,178.7 1,178.7 1,178.7 Temperature, F 119 119 119 Temperature, K 321.5 321.5 321.5 Exit velocity, ft/min 5,298 5,298 5,298 Exit velocity, m/s 26.91 26.91 26.91 LC-X (km) -1267.800 -1267.790 -1267.750 LC-Y (km) -241.690 -241.784 -241.884 

## Navajo G.S. Stack Data **(a)**

09000064811c2027 

# Baseline stack data 1/18/2013