fine total fine soil EC

MMBtu/day MMBtu/hr % ton/day lb/hr lb/MMBtu 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 51.26 4,271 0.486 0.0260 228.66 153.20 (f) 86.89 (f) 66.31 (f) 63.9 (g) 2.45 (g) 39.45 (h) 4.27 (i) 4.18 35.18 (j) 192.65

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 50.49 4,208 0.446 0.0210 197.89 132.59 (f) 75.20 (f) 57.39 (f) 55.3 (g) 2.12 (g) 42.27 (h) 4.58 (i) 4.48 37.69 (j) 174.86

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 50.18 4,182 0.457 0.0310 283.88 190.20 (f) 107.87 (f) 82.33 (f) 79.3 (g) 3.05 (g) 41.08 (h) 4.45 (i) 4.36 36.63 (j) 231.28

Total PM10

total coarse H2SO4 SO4

(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 Emissions Including Speciated PM10 Emissions 

Filterable PM10 Condensable PM10

Fine

Maximum Filterable

PM Emissions

Description

Navajo Units 1, 2, and 3

Baseline Conditions

Maximum SO2 Emissions (c) Maximum NOx Emissions (d) Maximum Heat Input (a)

(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. 

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.

(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.

Facility Unit organic

Maximum 

Sulfur 

Content (b)

(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”, William 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.

09000064811c2027 Baseline 1/16/2013
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 2,111 0.240 0.0260 228.66 153.20 (f) 86.89 (f) 66.31 (f) 63.9 (g) 2.45 (g) 39.45 (h) 4.27 (i) 4.18 35.18 (j) 192.65

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 2,262 0.240 0.0210 197.89 132.59 (f) 75.20 (f) 57.39 (f) 55.3 (g) 2.12 (g) 42.27 (h) 4.58 (i) 4.48 37.69 (j) 174.86

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 2,198 0.240 0.0310 283.88 190.20 (f) 107.87 (f) 82.33 (f) 79.3 (g) 3.05 (g) 41.08 (h) 4.45 (i) 4.36 36.63 (j) 231.28

Maximum Emissions Including Speciated PM10 Emissions 

Total PM10

Filterable PM10 Condensable PM10

Fine

Maximum Filterable

PM Emissions

Unit Description total

Maximum Heat Input (a)

Navajo Units 1, 2, and 3

Control Option 1A: Low NOx Burners and Separated Overfire Air

Facility H2SO4 organic

Maximum SO2 Emissions (c) Maximum NOx Emissions (d)

coarse total SO4

Maximum 

Sulfur 

Content (b)

09000064811c2027 LNB SOFA 1/16/2013
use this

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 lb/hr lb mole/hr lb mole/hr lb mole/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 63% 19.00 1,583 0.180 0.0260 228.66 153.20 (f) 86.89 (f) 66.31 (f) 63.9 (g) 2.45 (g) 39.45 (h) 4.27 (i) 4.18 35.18 (j) 10.10 26.60 (k) 1.562 0.103 1.46 (l) 24.84 2.484 (m) 0.00 10.10 4.27 4.18 126.34

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 60% 20.35 1,696 0.180 0.0210 197.89 132.59 (f) 75.20 (f) 57.39 (f) 55.3 (g) 2.12 (g) 42.27 (h) 4.58 (i) 4.48 37.69 (j) 10.82 28.50 (k) 1.673 0.110 1.56 (l) 26.62 2.662 (m) 0.00 10.82 4.58 4.48 117.47

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 61% 19.78 1,648 0.180 0.0310 283.88 190.20 (f) 107.87 (f) 82.33 (f) 79.3 (g) 3.05 (g) 41.08 (h) 4.45 (i) 4.36 36.63 (j) 10.51 27.69 (k) 1.626 0.107 1.52 (l) 25.87 2.587 (m) 0.00 10.51 4.45 4.36 148.95

(m) Ammonia contorl due to the effects of the air preheater and wet scrubber is consevatively assumed to be 90% based on "Estimating Ammonia Emissions from Stationary Power Plants", EPRI 1017985, Technical Update, April 2009.

total coarse

Fine

total

Excess NH3 (Slip) H2SO4

H2SO4 SO4 organic

(NH4)2SO4

/NH4HSO4 

(as 

H2SO4)

Total 

Effective 

H2SO4 for 

Modeling

Total 

Effective 

SO4 for 

Modeling

Total PM10 NH3 

Emissions

Total 

H2SO4 

before NH3 

interaction

Maximum Filterable

PM Emissions

Filterable PM10 Condensable PM10

(k) Ammonia slip is 5 ppmvd at 6% O2 for SNCR.

NH3 Slip NH3 H2SO4

Maximum Emissions Including Speciated PM10 Emissions 

Navajo Units 1, 2, and 3

Control Option 2: Selective Noncatalytic Reduction at 0.18 lb/MMBtu

Facility Unit Description

Maximum Heat Input (a)

Maximum 

Sulfur 

Content (b)

Maximum SO2 Emissions (c) Maximum NOx Emissions (d)

09000064811c2027 SNCR 0.18 1/16/2013
use this

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 lb/hr lb mole/hr lb mole/hr lb mole/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 69% 15.83 1,319 0.150 0.0260 228.66 153.20 (f) 86.89 (f) 66.31 (f) 63.9 (g) 2.45 (g) 39.45 (h) 4.27 (i) 4.18 35.18 (j) 10.10 26.60 (k) 1.562 0.103 1.46 (l) 24.84 2.484 (m) 0.00 10.10 4.27 4.18 126.34

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 66% 16.96 1,414 0.150 0.0210 197.89 132.59 (f) 75.20 (f) 57.39 (f) 55.3 (g) 2.12 (g) 42.27 (h) 4.58 (i) 4.48 37.69 (j) 10.82 28.50 (k) 1.673 0.110 1.56 (l) 26.62 2.662 (m) 0.00 10.82 4.58 4.48 117.47

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 67% 16.48 1,374 0.150 0.0310 283.88 190.20 (f) 107.87 (f) 82.33 (f) 79.3 (g) 3.05 (g) 41.08 (h) 4.45 (i) 4.36 36.63 (j) 10.51 27.69 (k) 1.626 0.107 1.52 (l) 25.87 2.587 (m) 0.00 10.51 4.45 4.36 148.95

(m) Ammonia contorl due to the effects of the air preheater and wet scrubber is consevatively assumed to be 90% based on "Estimating Ammonia Emissions from Stationary Power Plants", EPRI 1017985, Technical Update, April 2009.

(k) Ammonia slip is 5 ppmvd at 6% O2 for SNCR.

total coarse

Fine

total H2SO4 SO4

(NH4)2SO4

/NH4HSO4 

(as 

H2SO4)

Total 

Effective 

H2SO4 for 

Modeling

Total 

Effective 

SO4 for 

Modeling

Total PM10

organic

H2SO4 Excess NH3 (Slip) NH3 

Emissions

H2SO4

Maximum Emissions Including Speciated PM10 Emissions 

Navajo Units 1, 2, and 3

Control Option 2: Selective Noncatalytic Reduction at 0.15 lb/MMBtu

Facility Unit Description

Maximum Heat Input (a)

Maximum 

Sulfur 

Content (b)

Maximum SO2 Emissions (c) Maximum NOx Emissions (d) Maximum Filterable

PM Emissions

Filterable PM10 Condensable PM10 Total 

H2SO4 

before NH3 

interaction

NH3 Slip NH3

09000064811c2027 SNCR 0.15 1/16/2013
30.01 46.01

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 lb mole/hr lb mole/hr lb mole/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, SCR, 

wet FGD

211,074 8,795 0.593 5.85 487.75 0.055 84% 8.44 704 0.080 0.026 228.66 153.20 (f) 86.89 (f) 66.31 (f) 63.9 (g) 2.45 (g) 69.99 (h) 34.81 (i) 35.18 (j) 82.29 3.99 (k) 0.234 0.839 -0.60 (l) 0.00 59.32 22.97 34.81 34.10 223.19 435.95 35.18

Navajo 2

750 MW, PC, 

bituminous coal, dry 

bottom, tangential 

fired, LNB, SOFA, 

hot side ESP, SCR, 

wet FGD

226,163 9,423 0.593 6.32 526.92 0.056 82% 9.05 754 0.080 0.021 197.89 132.59 (f) 75.20 (f) 57.39 (f) 55.3 (g) 2.12 (g) 74.99 (h) 37.30 (i) 37.69 (j) 88.17 4.27 (k) 0.251 0.899 -0.65 (l) 0.00 63.56 24.61 37.30 36.54 207.58 467.12 37.69

Navajo 3

750 MW, PC, 

bituminous coal, dry 

bottom, tangential 

fired, LNB, SOFA, 

hot side ESP, SCR, 

wet FGD

219,778 9,157 0.593 6.91 576.17 0.063 82% 8.79 733 0.080 0.031 283.88 190.20 (f) 107.87 (f) 82.33 (f) 79.3 (g) 3.05 (g) 72.87 (h) 36.24 (i) 36.63 (j) 85.68 4.15 (k) 0.244 0.874 -0.63 (l) 0.00 61.76 23.92 36.24 35.50 263.07 453.93 36.63

0.5% 

conversion

NH3 0.75 ppmvd 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

As a general rule of thumb, 95% iof the NOx 

emissions are attrubitablle to NO and 5% are 

due to NO2.

Control Option 4: Low NOx Burners, Separated Overfire Air, and Selective Catalytic Reduction (Units 1, 2 & 3) 

Facility Unit Description

Maximum Heat Input (a)

Maximum Emissions Including Speciated PM10 Emissions

Navajo Units 1, 2, and 3

Total PM10 NO2

Condensable PM10 Total H2SO4 

before NH3 

interaction

Maximum Filterable

PM Emissions

total

NH3

(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. 

(NH4)2SO

4/NH4HSO

4 (as 

H2SO4)

H2SO4

(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.

organic

(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.

(h) Total condensable PM10 is the sum of H2SO4 and organic condensable PM10 emissions. 

(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.

NO

(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”, William Battye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 

NH3 Slip

Total 

Effective 

H2SO4 for 

Modeling

Maximum NOx Emissions (d)

(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. 

(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 coarse

Fine

Total 

Effective 

SO4 for 

Modeling

(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 SO2 Emissions (c) Excess NH3 (Slip)

Maximum Filterable PM10

Sulfur 

Content (b)

H2SO4

09000064811c2027 SCR 1/16/2013
Salt River Project Navajo Generating Station - Class I Modeling 

Results are based on the 3-year average of the 8th highest delta-dv 

CALPOST Method 6 (old IMPROVE equation)

Baseline LNB/OFA/SNCR @ 

0.24 lb/MMBtu

LNB/OFA/SNCR @ 

0.18 lb/MMBtu

LNB/OFA/SNCR @ 

0.15 lb/MMBtu

AECOM NH 3 AECOM NH 3 AECOM NH 3 AECOM NH 3

CALPUFF V5.8 CALPUFF V5.8 CALPUFF V5.8 CALPUFF V5.8

Arches NP 2.05 1.51 1.30 1.17

Bryce Canyon NP 2.00 1.58 1.40 1.30

Canyonlands NP 2.47 1.96 1.67 1.49

Capitol Reef NP 2.68 2.31 2.18 2.05

Grand Canyon NP 2.56 2.29 2.21 2.12

Mazatzal W 0.71 0.47 0.41 0.37

Mesa Verde NP 1.42 1.04 0.84 0.74

Petrified Forest NP 1.52 1.14 0.99 0.90

Pine Mountain W 0.66 0.46 0.39 0.36

Sycamore Canyon W 1.31 0.92 0.81 0.75

Zion NP 1.83 1.47 1.31 1.20

Baseline LNB/OFA/SNCR @ 

0.24 lb/MMBtu

LNB/OFA/SNCR @ 

0.18 lb/MMBtu

LNB/OFA/SNCR @ 

0.15 lb/MMBtu

CMAQ Monthly Ave CMAQ Monthly 

Ave

CMAQ Monthly 

Ave CMAQ Monthly Ave

CALPUFF V6.4 CALPUFF V6.4 CALPUFF V6.4 CALPUFF V6.4

Arches NP 1.27 0.76 0.62 0.58

Bryce Canyon NP 1.43 0.91 0.72 0.63

Canyonlands NP 1.60 1.05 0.90 0.82

Capitol Reef NP 2.78 1.85 1.50 1.32

Grand Canyon NP 2.22 1.69 1.58 1.50

Mazatzal W 0.29 0.20 0.20 0.20

Mesa Verde NP 0.75 0.42 0.36 0.33

Petrified Forest NP 0.99 0.57 0.49 0.47

Pine Mountain W 0.22 0.20 0.20 0.20

Sycamore Canyon W 0.65 0.47 0.44 0.44

Zion NP 1.01 0.57 0.52 0.50

Class I Area

Class I Area
LNB/OFA/SCR @ 

0.08 lb/MMBtu

AECOM NH 3

CALPUFF V5.8

0.92

1.11

1.26

1.74

2.05

0.34

0.52

0.72

0.30

0.59

1.00

LNB/OFA/SCR @ 

0.08 lb/MMBtu

CMAQ Monthly 

Ave

CALPUFF V6.4

0.53

0.75

0.75

1.28

1.68

0.24

0.34

0.50

0.24

0.44

0.59