### For copying to Word version of tables CALPUFF lines at lower right Highlight numbers portion of table here, copy; then goto Word, highlight numbers section of its table, paste 

## Revised **6/1/2010 EPA revised version of ENSR spreadsheet**  baseline new PM fine soil Filterable PM10 Condensable PM10 (CPM) Filterable PM fine total fine soil EC total H2SO4 SO4 organic H2SO4 HCl HF HCl + HFHCl+HF+ PmfineHCl+HF+

Pmfine EC coarse SO4 organic Max Heat Input SO2 NOx H2SO4 NH3 PM coarsePM fine soil PM fine

EC inorganic

(SO4) organic

(SOA) Max Stack

Test MMBtu/hr (a) Btu/lb

(b) % wt.

(b) lb/MMBtu

(c) lb/hr lb/MMBtu (c) lb/hr lb/MMBtu (c) lb/hr Basis lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/mmbtulb/mmbtulb/Mmbtu lb/hr lb/hr lb/mmbtu lb/mmbtulb/mmbtulb/mmbtulb/mmbtu MMBtu/hrlb/MMBtulb/MMBtulb/MMBtulb/MMBtulb/MMBtulb/MMBtulb/MMBtulb/MMBtulb/MMBtulb/MMBtu

1 Bituminous Coal, 190 MW, PC Wall-Fired, Dry Bottom, Venturi Scrubber, Wet FGD NA 0% 0% 2,349 8,880 0.772 0.86 2,020.14 0.22 522.54 0.033 77.52 Stack Test 55.04 (d) 15.50 39.5 (d) 38.07 1.46 (f) 10.94 1.54 (g) 1.51 9.40 (i) 65.97 0.00066 0 0 0 38.07 0.016 0.00062 0.00660.00064 0.0040 Unit 1 2,349 0.22 0.86 0.00066 0 0.0066 0.016 0.00062 0.00064 0.0040 0.033

2Bituminous Coal, 190 MW, PC Wall-Fired, Dry Bottom, Venturi Scrubber, Wet FGD NA 0% 0% 2,352 8,880 0.772 0.68 1,599.47 0.26 615.12 0.050 117.61 Stack Test 83.50 (d) 23.52 60.0 (d) 57.76 2.22 (f) 10.95 1.54 (g) 1.51 9.41 (i) 94.45 0.00066 0 0 0 57.76 0.025 0.00094 0.01000.00064 0.0040 Unit 2 2,352 0.26 0.68 0.00066 0 0.0100 0.025 0.00094 0.00064 0.0040 0.050

3Bituminous Coal, 253 MW, PC Wall-Fired, Dry Bottom, Venturi Scrubber, Wet FGD NA 0% 0% 3,032 8,880 0.772 0.65 1,970.80 0.34 1,042.09 0.040 121.28 Stack Test 86.11 (d) 24.26 61.9 (d) 59.56 2.29 (f) 14.12 1.99 (g) 1.95 12.13 (i) 100.23 0.00066 0 0 0 59.56 0.020 0.00075 0.00800.00064 0.0040 Unit 3 3,032 0.34 0.65 0.00066 0 0.0080 0.020 0.00075 0.00064 0.0040 0.040

4Bituminous Coal, 818 MW, PC Cell Burner, Dry Bottom, Fabric Filter, Semi-Dry FGD NA 0% 0% 8,000 8,880 0.772 0.63 5,015.98 0.25 2,026.10 0.025 197.75 Stack Test 181.926 (e) 77.12 104.81 (e)100.93 3.88 (f) 32.38 0.38 (h) 0.37 32.00 (i) 214.31 0.00005 0 0 0 100.93 0.013 0.00048 0.00960.00005 0.0040 Unit 4 8,000 0.25 0.63 0.00005 0 0.0096 0.013 0.00048 0.00005 0.0040 0.025

5Bituminous Coal, 818 MW, PC Cell Burner, Dry Bottom, Fabric Filter, Semi-Dry FGD NA 0% 0% 8,051 8,880 0.772 0.56 4,508.56 0.26 2,131.85 0.012 94.09 Stack Test 86.559 (e) 36.69 49.87 (e) 48.02 1.85 (f) 32.59 0.38 (h) 0.37 32.20 (i) 119.14 0.00005 0 0 0 48.02 0.006 0.00023 0.00460.00005 0.0040 Unit 5 8,051 0.26 0.56 0.00005 0 0.0046 0.006 0.00023 0.00005 0.0040 0.012

(a) Maximum heat input rate are based worst-case daily emissions for calendar years 2002 through 2006. EPA revised to take 2001 max for units 1, 3, 5 fc0 fc0 fc0 (b) Higher heating values and sulfur content are based on the average values for calendar years 2002 through 2006. 

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals After copying these to text file, 

### CALPUFF input lines replace 'CRLF' with newline (d) For a dry bottom boiler fired with bituminous coal and equipped with a scrubber, total filterable PM10 is 71% of filterable PM and fine filterable PM10 is 51% of filterable PM based on AP-42, Table 1.1-6. Max Heat Input SO2 NOx H2SO4 NH3 PM coarsePM fine soil PM fine

EC inorganic

(SO4) organic

(SOA) Max Stack

Test (e) For a dry bottom boiler fired with bituminous coal and equipped with a bagouse, total filterable PM10 is 92% of filterable PM and fine filterable PM10 is 53% of filterable PM based on AP-42, Table 1.1-6. MMBtu/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr SO2 SO4 NOX HNO3 NO3 SOA PMF PMC EC Unit 1 2,349 522.54 2,020.14 1.54 0 15.50 38.07 1.46 1.51 9.40 77.52 Unit 1 522.54 1.512020.14 0 0 9.40 38.07 15.50 1.46 1 ! SRCNAM = FCPP1 !CRLF 1 ! X = -1016.21601, -301.69621, 75.9, 1625.5, 6.47, 20.73, 323.15, 0, 522.54, 1.51, 2020.14, CRLF 0, 0, 9.4, 38.07, 15.5, 1.46 !CRLF 1 ! FMFAC = 1.0 ! !END!

Unit 2 2,352 615.12 1,599.47 1.54 0 23.52 57.76 2.22 1.51 9.41 117.61 Unit 2 615.12 1.51 1599.47 0 0 9.41 57.76 23.52 2.22 2 ! SRCNAM = FCPP2 !CRLF 2 ! X = -1016.21601, -301.69621, 75.9, 1625.5, 6.47, 20.73, 323.15, 0, 615.12, 1.51, 1599.47, CRLF 0, 0, 9.41, 57.76, 23.52, 2.22 !CRLF 2 ! FMFAC = 1.0 ! !END!

Unit 3 3,032 1042.09 1,970.80 1.99 0 24.26 59.56 2.29 1.95 12.13 121.28 Unit 3 1042.09 1.951970.80 0 0 12.13 59.56 24.26 2.29 3 ! SRCNAM = FCPP3 !CRLF 3 ! X = -1016.19928, -301.77622, 76.2, 1625.27, 4.57, 23.77, 323.15, 0, 1042.09, 1.95, 1970.8, CRLF 0, 0, 12.13, 59.56, 24.26, 2.29 !CRLF 3 ! FMFAC = 1.0 ! !END! Unit 4 8,000 2026.10 5,015.98 0.38 0 77.12 100.93 3.88 0.37 32.00 197.75 Unit 4 2026.10 0.375015.98 0 0 32.00 100.93 77.12 3.88 4 ! SRCNAM = FCPP4 !CRLF 4 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, 2026.1, 0.37, 5015.98, CRLF 0, 0, 32, 100.93, 77.12, 3.88 !CRLF 4 ! FMFAC = 1.0 ! !END! Unit 5 8,051 2131.85 4,508.56 0.38 0 36.69 48.02 1.85 0.37 32.20 94.09 Unit 5 2131.85 0.374508.56 0 0 32.20 48.02 36.69 1.85 5 ! SRCNAM = FCPP5 !CRLF 5 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, 2131.85, 0.37, 4508.56, CRLF 0, 0, 32.2, 48.02, 36.69, 1.85 !CRLF 5 ! FMFAC = 1.0 ! !END! Revisions 4/5/10 Set HCl and HF to zero - so Pmfine unchanged from Aecom values Units 1 and 2 summed, unit3, and units 4 and 5 summed SO2 SO4 NOX HNO3 NO3 SOA PMF PMC EC Units 1 & 2 1137.66 3.023619.61 0.00 0.00 18.81 95.83 39.02 3.68 1 ! SRCNAM = FCPP12 !CRLF 1 ! X = -1016.21601, -301.69621, 75.9, 1625.5, 6.47, 20.73, 323.15, 0, 1137.66, 3.02, 3619.61, CRLF 0, 0, 18.81, 95.83, 39.02, 3.68 !CRLF 1 ! FMFAC = 1.0 ! !END! Unit 3 1042.09 1.951970.80 0.00 0.00 12.13 59.56 24.26 2.29 2 ! SRCNAM = FCPP3 !CRLF 2 ! X = -1016.19928, -301.77622, 76.2, 1625.27, 4.57, 23.77, 323.15, 0, 1042.09, 1.95, 1970.8, CRLF 0, 0, 12.13, 59.56, 24.26, 2.29 !CRLF 2 ! FMFAC = 1.0 ! !END! Units 4 & 5 4157.95 0.749524.54 0.00 0.00 64.20 148.95 113.81 5.73 3 ! SRCNAM = FCPP45 !CRLF 3 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, 4157.95, 0.74, 9524.54, CRLF 0, 0, 64.2, 148.95, 113.81, 5.73 !CRLF 3 ! FMFAC = 1.0 ! !END! 

## APS Four Corners Plant - BART Determination Modeling

**Baseline Conditions**

(c) Baseline NOx, SO2 and filterable PM emissions are based worst-case daily emissions received on March 2, 2007 and revised April 26, 2007. EPA Revised to take 2001 max NOx for units 1, 2, 3, 5, and revised PMFine Filterable PM10 New BART ControlsPercent

NOx ControlPercent

PM Control Higher Heating Value Unit Maximum NOx Emissions coarse Max. Heat Input Condensable PM10 Total PM10 Maximum SO2 Emissions

(i) For pulverized coal-fired boilers with an FGD system, total condensable organic PM10 emissions factor is 0.004 lb/MMBtu based on AP-42, Table 1.1-5. (g) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants," EPRI, Technical Update, March 2008 and Hardman et al., 1998. For coal-fired boilers, H2SO4 emissions are determined from "(Q)(98.06/64.04)(F1+S2)(F2)" where Q is the uncontrolled SO2 emission rate (in lb/hr, calculated from heat rate, fuel S content, and 95% of fuel sulfur converted to SO2), F1 is the fuel factor (0.00111 for western bituminous coal), and F2 is the product of the control factors (0.9 for an air preheater, 0.65 for a venturi scrubber, and 0.10 for a baghouse or cold-side wet ESP). EPA revised air preheater factor to 0.36 based on EPRI 2010 update. (h) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants," EPRI, Technical Update, March 2008 and Hardman et al., 1998. For coal-fired boilers, H2SO4 emissions are determined from "(Q)(98.06/64.04)(F1+S2)(F2)" where Q is the uncontrolled SO2 emission rate (in lb/hr, calculated from heat rate, fuel S content, and 95% of fuel sulfur converted to SO2), F1 is the fuel factor (0.00111 for western bituminous coal), and F2 is the product of the control factors (0.9 for an air preheater, 0.65 for a venturi scrubber, and 0.10 for a baghouse or cold-side wet ESP). EPA revised air preheater factor to 0.36 based on EPRI 2010 update. Maximum Filterable PM Emissions Description

(f) 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. total Fuel Sulfur Content

09000064817e49bb fc0 Baseline Case 7/28/2014Spreadsheet originally developed by ENSR, edited by A.Lee and S.Bohning of EPA, 2009-05-08 

### For copying to Word version of tables CALPUFF lines at lower right Highlight numbers portion of table here, copy; then goto Word, highlight numbers section of its table, paste 

## Revised **6/1/2010 EPA revised version of ENSR spreadsheet**  fc1 **new PM fine soil** Filterable PM10 Condensable PM10 (CPM) Filterable PM fine total fine soil EC total H2SO4 SO4 organic H2SO4 HCl HF HCl + HFHCl+HF+ PmfineHCl+HF+

Pmfine EC coarse SO4 organic Max Heat Input SO2 NOx H2SO4 NH3 PM coarsePM fine soil PM fine

EC inorganic

(SO4) organic

(SOA)Max Stack

Test MMBtu/hr (a) Btu/lb

(b) % wt.

(b) lb/MMBtu

(c) lb/hr lb/MMBtu (c) lb/hr lb/MMBtu (c) lb/hr Basis lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/mmbtulb/mmbtulb/Mmbtu lb/hr lb/hr lb/mmbtu lb/mmbtulb/mmbtulb/mmbtulb/mmbtu MMBtu/hrlb/MMBtulb/MMBtulb/MMBtulb/MMBtulb/MMBtulb/MMBtulb/MMBtulb/MMBtulb/MMBtulb/MMBtu

1 Bituminous Coal, 190 MW, PC Wall-Fired, Dry Bottom, ESP, Venturi Scrubber, Wet FGD ESP 0% 52% 2,349 8,880 0.772 0.860 2,020.14 0.22 522.54 0.014 33.83 Stack Test 31.12 (d) 13.19 17.9 (d) 17.26 0.66 (f) 10.51 1.11 (g) 1.09 9.40 (i) 41.63 0.00047 0 0 0 17.26 0.007 0.00028 0.00560.00046 0.0040 Unit 1 2,349 0.22 0.86 0.00047 0 0.0056 0.007 0.00028 0.00046 0.0040 0.014

2Bituminous Coal, 190 MW, PC Wall-Fired, Dry Bottom, ESP, Venturi Scrubber, Wet FGD ESP 0% 59% 2,352 8,880 0.77 0.680 1,599.47 0.26 615.12 0.017 39.96 Stack Test 36.76 (d) 15.58 21.2 (d) 20.39 0.78 (f) 10.52 1.11 (g) 1.09 9.41 (i) 47.28 0.00047 0 0 0 20.39 0.009 0.00033 0.00660.00046 0.0040 Unit 2 2,352 0.26 0.68 0.00047 0 0.0066 0.009 0.00033 0.00046 0.0040 0.017

3Bituminous Coal, 253 MW, PC Wall-Fired, Dry Bottom, ESP, Venturi Scrubber, Wet FGD ESP 0% 59% 3,032 8,880 0.77 0.650 1,970.80 0.34 1042.09 0.015 46.24 Stack Test 42.54 (d) 18.03 24.5 (d) 23.60 0.91 (f) 13.56 1.43 (g) 1.40 12.13 (i) 56.10 0.00047 0 0 0 23.60 0.008 0.00030 0.00590.00046 0.0040 Unit 3 3,032 0.34 0.65 0.00047 0 0.0059 0.008 0.000300.00046 0.0040 0.015

4Bituminous Coal, 818 MW, PC Cell Burner, Dry Bottom, Fabric Filter, Semi-Dry FGD None 0% 0% 8,000 8,880 0.77 0.627 5,015.98 0.25 2026.10 0.025 197.75 Stack Test 181.926 (e)77.12 104.81 (e)100.93 3.88 (f) 32.38 0.38 (h) 0.37 32.00 (i)214.31 0.00005 0 0 0 100.93 0.013 0.00048 0.00960.00005 0.0040 Unit 4 8,000 0.25 0.63 0.00005 0 0.0096 0.013 0.00048 0.00005 0.0040 0.025

5Bituminous Coal, 818 MW, PC Cell Burner, Dry Bottom, Fabric Filter, Semi-Dry FGD None 0% 0% 8,051 8,880 0.772 0.560 4,508.56 0.26 2131.85 0.012 94.09 Stack Test 86.559 (e) 36.69 49.87 (e) 48.02 1.85 (f) 32.59 0.38 (h) 0.37 32.20 (i) 119.14 0.00005 0 0 0 48.02 0.006 0.00023 0.00460.00005 0.0040 Unit 5 8,051 0.26 0.56 0.00005 0 0.0046 0.006 0.00023 0.00005 0.0040 0.012

(a) Maximum heat input rate are based worst-case daily emissions for calendar years 2002 through 2006. EPA revised to take 2001 max for units 1, 3, 5 fc1 fc1 fc1 (b) Higher heating values and sulfur content are based on the average values for calendar years 2002 through 2006. 

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals After copying these to text file, 

### CALPUFF input lines replace 'CRLF' with newline (d) For a dry bottom boiler fired with bituminous coal and equipped with a scrubber, total filterable PM10 is 71% of filterable PM and fine filterable PM10 is 51% of filterable PM based on AP-42, Table 1.1-6. Max Heat Input SO2 NOx H2SO4 NH3 PM coarsePM fine soil PM fine

EC inorganic

(SO4) organic

(SOA)Max Stack

Test (e) For a dry bottom boiler fired with bituminous coal and equipped with a bagouse, total filterable PM10 is 92% of filterable PM and fine filterable PM10 is 53% of filterable PM based on AP-42, Table 1.1-6. MMBtu/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr SO2 SO4 NOX HNO3 NO3 SOA PMF PMC EC Unit 1 2,349 522.54 2,020.14 1.11 0 13.19 17.26 0.66 1.09 9.40 33.83 Unit 1 522.54 1.092020.14 0 0 9.40 17.26 13.19 0.66 1 ! SRCNAM = FCPP1 !CRLF 1 ! X = -1016.21601, -301.69621, 75.9, 1625.5, 6.47, 20.73, 323.15, 0, 522.54, 1.09, 2020.14, 0, 0, 9.4, 17.26, 13.19, 0.66 !CRLF 1 ! FMFAC = 1.0 ! !END! Unit 2 2,352 615.12 1,599.47 1.11 0 15.58 20.39 0.78 1.09 9.41 39.96 Unit 2 615.12 1.091599.47 0 0 9.41 20.39 15.58 0.78 2 ! SRCNAM = FCPP2 !CRLF 2 ! X = -1016.21601, -301.69621, 75.9, 1625.5, 6.47, 20.73, 323.15, 0, 615.12, 1.09, 1599.47, 0, 0, 9.41, 20.39, 15.58, 0.78 !CRLF 2 ! FMFAC = 1.0 ! !END!

Unit 3 3,032 1042.091,970.80 1.43 0 18.03 23.60 0.91 1.40 12.13 46.24 Unit 3 1042.09 1.401970.80 0 0 12.13 23.60 18.03 0.91 3 ! SRCNAM = FCPP3 !CRLF 3 ! X = -1016.19928, -301.77622, 76.2, 1625.27, 4.57, 23.77, 323.15, 0, 1042.09, 1.4, 1970.8, 0, 0, 12.13, 23.6, 18.03, 0.91 !CRLF 3 ! FMFAC = 1.0 ! !END! Unit 4 8,000 2026.105,015.98 0.38 0 77.12 100.93 3.88 0.37 32.00 197.75 Unit 4 2026.10 0.375015.98 0 0 32.00 100.93 77.12 3.88 4 ! SRCNAM = FCPP4 !CRLF 4 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, 2026.1, 0.37, 5015.98, 0, 0, 32, 100.93, 77.12, 3.88 !CRLF 4 ! FMFAC = 1.0 ! !END! Unit 5 8,051 2131.854,508.56 0.38 0 36.69 48.02 1.85 0.37 32.20 94.09 Unit 5 2131.85 0.374508.56 0 0 32.20 48.02 36.69 1.85 5 ! SRCNAM = FCPP5 !CRLF 5 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, 2131.85, 0.37, 4508.56, 0, 0, 32.2, 48.02, 36.69, 1.85 !CRLF 5 ! FMFAC = 1.0 ! !END! Revisions 4/5/10 Set HCl and HF to zero - so Pmfine unchanged from Aecom values For conservativism, assume the PM control is a cold side ESP, not a baghouse, so less H2SO4 is removed (use 0.72 (EPRI 2010 - cold side ESP,PRB subbitum coal) instead of baghouse number (0.1) **Units 1 and 2 summed, unit3, and units 4 and 5 summed** SO2 SO4 NOX HNO3 NO3 SOA PMF PMC EC Units 1 & 21137.66 2.183619.61 0.00 0.00 18.81 37.65 28.77 1.44 **1 ! SRCNAM = FCPP12 !CRLF 1 ! X = -1016.21601, -301.69621, 75.9, 1625.5, 6.47, 20.73, 323.15, 0, 1137.66, 2.18, 3619.61, 0, 0, 18.81, 37.65, 28.77, 1.44 !CRLF 1 ! FMFAC = 1.0 ! !END!** Unit 3 1042.09 1.401970.80 0.00 0.00 12.13 23.60 18.03 0.91 **2 ! SRCNAM = FCPP3 !CRLF 2 ! X = -1016.19928, -301.77622, 76.2, 1625.27, 4.57, 23.77, 323.15, 0, 1042.09, 1.4, 1970.8, 0, 0, 12.13, 23.6, 18.03, 0.91 !CRLF 2 ! FMFAC = 1.0 ! !END!** Units 4 & 54157.95 0.749524.54 0.00 0.00 64.20 148.95 113.81 5.73 **3 ! SRCNAM = FCPP45 !CRLF 3 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, 4157.95, 0.74, 9524.54, 0, 0, 64.2, 148.95, 113.81, 5.73 !CRLF 3 ! FMFAC = 1.0 ! !END!** 

## APS Four Corners Plant - BART Determination Modeling

**PM10 Control Case fc1**

Unit Description New BART Controls Percent

NOx ControlPercent PM

Control Max. Heat

Input Higher

Heating Value Fuel Sulfur

Content Maximum NOx

Emissions Maximum SO2 Emissions Condensable PM10 Total PM10 total coarse Fine

(i) For pulverized coal-fired boilers with an FGD system, total condensable organic PM10 emissions factor is 0.004 lb/MMBtu based on AP-42, Table 1.1-5. (c) Baseline NOx, SO2 and filterable PM emissions are based worst-case daily emissions received on March 2, 2007 and revised April 26, 2007. EPA Revised to take 2001 max NOx for units 1, 2, 3, 5

(f) 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. (g) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants," EPRI, Technical Update, March 2008 and Hardman et al., 1998. For coal-fired boilers, H2SO4 emissions are determined from "(Q)(98.06/64.04)(F1+S2)(F2)" where Q is the uncontrolled SO2 emission rate (in lb/hr, calculated from heat rate, fuel S content, and 95% of fuel sulfur converted to SO2), F1 is the fuel factor (0.00111 for western bituminous coal), and F2 is the product of the control factors (0.9 for an air preheater, 0.65 for a venturi scrubber, and 0.10 for a baghouse or cold-side wet ESP). EPA revised air preheater factor to 0.36 based on EPRI 2010 update. (h) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants," EPRI, Technical Update, March 2008 and Hardman et al., 1998. For coal-fired boilers, H2SO4 emissions are determined from "(Q)(98.06/64.04)(F1+S2)(F2)" where Q is the uncontrolled SO2 emission rate (in lb/hr, calculated from heat rate, fuel S content, and 95% of fuel sulfur converted to SO2), F1 is the fuel factor (0.00111 for western bituminous coal), and F2 is the product of the control factors (0.9 for an air preheater, 0.65 for a venturi scrubber, and 0.10 for a baghouse or cold-side wet ESP). EPA revised air preheater factor to 0.36 based on EPRI 2010 update. Maximum Filterable PM Emissions Filterable PM10

09000064817e49bb fc1 PM Control 7/28/20145 ! SRCNAM = FCPP5 !CRLF 5 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, 2131.85, 0.37, 4508.56, 0, 0, 32.2, 48.02, 36.69, 1.85 !CRLF 5 ! FMFAC = 1.0 ! !END!

**1 ! SRCNAM = FCPP12 !CRLF 1 ! X = -1016.21601, -301.69621, 75.9, 1625.5, 6.47, 20.73, 323.15, 0, 1137.66, 2.18, 3619.61, 0, 0, 18.81, 37.65, 28.77, 1.44 !CRLF 1 ! FMFAC = 1.0 ! !END! 3 ! SRCNAM = FCPP45 !CRLF 3 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, 4157.95, 0.74, 9524.54, 0, 0, 64.2, 148.95, 113.81, 5.73 !CRLF 3 ! FMFAC = 1.0 ! !END!** 

09000064817e49bb fc1 PM Control 7/28/2014

### For copying to Word version of tables CALPUFF lines at lower right Highlight numbers portion of table here, copy; then goto Word, highlight numbers section of its table, paste 

## Revised **6/1/2010 EPA revised version of ENSR spreadsheet**  fc2 new PM fine soil Filterable PM10 Condensable PM10 (CPM) Filterable PM fine total fine soil EC total H2SO4 SO4 organic H2SO4 HCl HF HCl + HFHCl+HF+ PmfineHCl+HF+

Pmfine EC coarse SO4 organic Max Heat Input SO2 NOx H2SO4 NH3 PM coarsePM fine soil PM fine

EC inorganic

(SO4) organic

(SOA)Max Stack

Test MMBtu/hr (a) Btu/lb

(b) % wt.

(b) lb/MMBtu

(c) lb/hr lb/MMBtu (c) lb/hr lb/MMBtu (c) lb/hr Basis lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/mmbtulb/mmbtulb/Mmbtu lb/hr lb/hr lb/mmbtu lb/mmbtulb/mmbtulb/mmbtulb/mmbtu MMBtu/hrlb/MMBtulb/MMBtulb/MMBtulb/MMBtulb/MMBtulb/MMBtulb/MMBtulb/MMBtulb/MMBtulb/MMBtu

1 Bituminous Coal, 190 MW, PC Wall-Fired, Dry Bottom, Venturi Scrubber, Wet FGD LNB 45% 2,349 8,880 0.772 0.472 1,109.06 0.222 522.54 0.033 77.52 Stack Test 55.04 (d) 15.50 39.5 (d) 38.07 1.46 (f) 10.94 1.54 (g) 1.51 9.40 (i) 65.97 0.00066 0 0 0 38.07 0.016 0.00062 0.00660.00064 0.0040 Unit 1 2,349 0.22 0.47 0.00066 0 0.0066 0.016 0.000620.00064 0.0040 0.033

2Bituminous Coal, 190 MW, PC Wall-Fired, Dry Bottom, Venturi Scrubber, Wet FGD LNB 33% 2,352 8,880 0.772 0.456 1,073.25 0.262 615.12 0.050 117.61 Stack Test 83.50 (d) 23.52 60.0 (d) 57.76 2.22 (f) 10.95 1.54 (g) 1.51 9.41 (i) 94.45 0.00066 0 0 0 57.76 0.025 0.00094 0.01000.00064 0.0040 Unit 2 2,352 0.26 0.46 0.00066 0 0.0100 0.025 0.000940.00064 0.0040 0.050

3Bituminous Coal, 253 MW, PC Wall-Fired, Dry Bottom, Venturi Scrubber, Wet FGD LNB, OFA 44% 3,032 8,880 0.772 0.364 1,103.65 0.344 1,042.09 0.040 121.28 Stack Test 86.11 (d) 24.26 61.9 (d) 59.56 2.29 (f) 14.12 1.99 (g) 1.95 12.13 (i) 100.23 0.00066 0 0 0 59.56 0.020 0.00075 0.00800.00064 0.0040 Unit 3 3,032 0.34 0.36 0.00066 0 0.0080 0.020 0.00075 0.00064 0.0040 0.040

4Bituminous Coal, 818 MW, PC Cell Burner, Dry Bottom, Fabric Filter, Semi-Dry FGD LNB, OFA 29% 8,000 8,880 0.772 0.445 3,561.35 0.253 2,026.10 0.025 197.75 Stack Test 181.926 (e)77.12 104.81 (e)100.93 3.88 (f) 32.38 0.38 (h) 0.37 32.00 (i)214.31 0.00005 0 0 0 100.93 0.013 0.00048 0.00960.00005 0.0040 Unit 4 8,000 0.25 0.45 0.00005 0 0.0096 0.013 0.00048 0.00005 0.0040 0.025

5Bituminous Coal, 818 MW, PC Cell Burner, Dry Bottom, Fabric Filter, Semi-Dry FGD LNB, OFA 29% 8,051 8,880 0.772 0.398 3,201.08 0.265 2,131.85 0.012 94.09 Stack Test 86.559 (e) 36.69 49.87 (e) 48.02 1.85 (f) 32.59 0.38 (h) 0.37 32.20 (i) 119.14 0.00005 0 0 0 48.02 0.006 0.00023 0.00460.00005 0.0040 Unit 5 8,051 0.26 0.40 0.00005 0 0.0046 0.006 0.00023 0.00005 0.0040 0.012

(a) Maximum heat input rate are based worst-case daily emissions for calendar years 2002 through 2006. EPA revised to take 2001 max for units 1, 3, 5 fc2 fc2 fc2 (b) Higher heating values and sulfur content are based on the average values for calendar years 2002 through 2006. 

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals After copying these to text file, 

### CALPUFF input lines replace 'CRLF' with newline (d) For a dry bottom boiler fired with bituminous coal and equipped with a scrubber, total filterable PM10 is 71% of filterable PM and fine filterable PM10 is 51% of filterable PM based on AP-42, Table 1.1-6. Max Heat Input SO2 NOx H2SO4 NH3 PM coarsePM fine soil PM fine

EC inorganic

(SO4) organic

(SOA)Max Stack

Test (e) For a dry bottom boiler fired with bituminous coal and equipped with a bagouse, total filterable PM10 is 92% of filterable PM and fine filterable PM10 is 53% of filterable PM based on AP-42, Table 1.1-6. MMBtu/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr SO2 SO4 NOX HNO3 NO3 SOA PMF PMC EC Unit 1 2,349 522.54 1,109.06 1.54 0 15.50 38.07 1.46 1.51 9.40 77.52 Unit 1 522.54 1.511109.06 0 0 9.40 38.07 15.50 1.46 1 ! SRCNAM = FCPP1 !CRLF 1 ! X = -1016.21601, -301.69621, 75.9, 1625.5, 6.47, 20.73, 323.15, 0, 522.54, 1.51, 1109.06, CRLF 0, 0, 9.4, 38.07, 15.5, 1.46 !CRLF 1 ! FMFAC = 1.0 ! !END!
Unit 2 2,352 615.12 1,073.25 1.54 0 23.52 57.76 2.22 1.51 9.41 117.61 Unit 2 615.12 1.511073.25 0 0 9.41 57.76 23.52 2.22 2 ! SRCNAM = FCPP2 !CRLF 2 ! X = -1016.21601, -301.69621, 75.9, 1625.5, 6.47, 20.73, 323.15, 0, 615.12, 1.51, 1073.25, CRLF 0, 0, 9.41, 57.76, 23.52, 2.22 !CRLF 2 ! FMFAC = 1.0 ! !END!
Unit 3 3,032 1042.091,103.65 1.99 0 24.26 59.56 2.29 1.95 12.13 121.28 Unit 3 1042.09 1.951103.65 0 0 12.13 59.56 24.26 2.29 3 ! SRCNAM = FCPP3 !CRLF 3 ! X = -1016.19928, -301.77622, 76.2, 1625.27, 4.57, 23.77, 323.15, 0, 1042.09, 1.95, 1103.65, CRLF 0, 0, 12.13, 59.56, 24.26, 2.29 !CRLF 3 ! FMFAC = 1.0 ! !END! Unit 4 8,000 2026.103,561.35 0.38 0 77.12 100.93 3.88 0.37 32.00 197.75 Unit 4 2026.10 0.373561.35 0 0 32.00 100.93 77.12 3.88 4 ! SRCNAM = FCPP4 !CRLF 4 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, 2026.1, 0.37, 3561.35, CRLF 0, 0, 32, 100.93, 77.12, 3.88 !CRLF 4 ! FMFAC = 1.0 ! !END! Unit 5 8,051 2131.853,201.08 0.38 0 36.69 48.02 1.85 0.37 32.20 94.09 Unit 5 2131.85 0.373201.08 0 0 32.20 48.02 36.69 1.85 5 ! SRCNAM = FCPP5 !CRLF 5 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, 2131.85, 0.37, 3201.08, CRLF 0, 0, 32.2, 48.02, 36.69, 1.85 !CRLF 5 ! FMFAC = 1.0 ! !END! Revisions 4/5/10 Set HCl and HF to zero - so Pmfine unchanged from Aecom values **Units 1 and 2 summed, unit3, and units 4 and 5 summed** SO2 SO4 NOX HNO3 NO3 SOA PMF PMC EC Units 1 & 21137.66 3.022182.31 0.00 0.00 18.81 95.83 39.02 3.68 1 ! SRCNAM = FCPP12 !CRLF 1 ! X = -1016.21601, -301.69621, 75.9, 1625.5, 6.47, 20.73, 323.15, 0, 1137.66, 3.02, 2182.31, CRLF 0, 0, 18.81, 95.83, 39.02, 3.68 !CRLF 1 ! FMFAC = 1.0 ! !END! Unit 3 1042.09 1.951103.65 0.00 0.00 12.13 59.56 24.26 2.29 2 ! SRCNAM = FCPP3 !CRLF 2 ! X = -1016.19928, -301.77622, 76.2, 1625.27, 4.57, 23.77, 323.15, 0, 1042.09, 1.95, 1103.65, CRLF 0, 0, 12.13, 59.56, 24.26, 2.29 !CRLF 2 ! FMFAC = 1.0 ! !END! Units 4 & 54157.95 0.746762.43 0.00 0.00 64.20 148.95 113.81 5.73 3 ! SRCNAM = FCPP45 !CRLF 3 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, 4157.95, 0.74, 6762.43, CRLF 0, 0, 64.2, 148.95, 113.81, 5.73 !CRLF 3 ! FMFAC = 1.0 ! !END! 

## APS Four Corners Plant - BART Determination Modeling

**NOx Control Case fc2**

Unit Description New NOx BART Controls Percent

NOx Control Max. Heat

Input Higher

Heating Value Fuel Sulfur

Content Maximum NOx

Emissions Maximum Filterable PM Emissions Filterable PM10 Condensable PM10 Total PM10 total coarse Fine Maximum SO2 Emissions

(i) For pulverized coal-fired boilers with an FGD system, total condensable organic PM10 emissions factor is 0.004 lb/MMBtu based on AP-42, Table 1.1-5. (c) Baseline NOx, SO2 and filterable PM emissions are based worst-case daily emissions received on March 2, 2007 and revised April 26, 2007. EPA Revised to take 2001 max NOx for units 1, 2, 3, 5

(f) 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. (g) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants," EPRI, Technical Update, March 2008 and Hardman et al., 1998. For coal-fired boilers, H2SO4 emissions are determined from "(Q)(98.06/64.04)(F1+S2)(F2)" where Q is the uncontrolled SO2 emission rate (in lb/hr, calculated from heat rate, fuel S content, and 95% of fuel sulfur converted to SO2), F1 is the fuel factor (0.00111 for western bituminous coal), and F2 is the product of the control factors (0.9 for an air preheater, 0.65 for a venturi scrubber, and 0.10 for a baghouse or (h) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants," EPRI, Technical Update, March 2008 and Hardman et al., 1998. For coal-fired boilers, H2SO4 emissions are determined from "(Q)(98.06/64.04)(F1+S2)(F2)" where Q is the uncontrolled SO2 emission rate (in lb/hr, calculated from heat rate, fuel S content, and 95% of fuel sulfur converted to SO2), F1 is the fuel factor (0.00111 for western bituminous coal), and F2 is the product of the control factors (0.9 for an air preheater, 0.65 for a venturi scrubber, and 0.10 for a baghouse or

09000064817e49bb fc2_LNB 7/28/20143 ! SRCNAM = FCPP3 !CRLF 3 ! X = -1016.19928, -301.77622, 76.2, 1625.27, 4.57, 23.77, 323.15, 0, 1042.09, 1.95, 1103.65, CRLF 0, 0, 12.13, 59.56, 24.26, 2.29 !CRLF 3 ! FMFAC = 1.0 ! !END! 4 ! SRCNAM = FCPP4 !CRLF 4 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, 2026.1, 0.37, 3561.35, CRLF 0, 0, 32, 100.93, 77.12, 3.88 !CRLF 4 ! FMFAC = 1.0 ! !END! 5 ! SRCNAM = FCPP5 !CRLF 5 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, 2131.85, 0.37, 3201.08, CRLF 0, 0, 32.2, 48.02, 36.69, 1.85 !CRLF 5 ! FMFAC = 1.0 ! !END!

1 ! SRCNAM = FCPP12 !CRLF 1 ! X = -1016.21601, -301.69621, 75.9, 1625.5, 6.47, 20.73, 323.15, 0, 1137.66, 3.02, 2182.31, CRLF 0, 0, 18.81, 95.83, 39.02, 3.68 !CRLF 1 ! FMFAC = 1.0 ! !END! 2 ! SRCNAM = FCPP3 !CRLF 2 ! X = -1016.19928, -301.77622, 76.2, 1625.27, 4.57, 23.77, 323.15, 0, 1042.09, 1.95, 1103.65, CRLF 0, 0, 12.13, 59.56, 24.26, 2.29 !CRLF 2 ! FMFAC = 1.0 ! !END! 3 ! SRCNAM = FCPP45 !CRLF 3 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, 4157.95, 0.74, 6762.43, CRLF 0, 0, 64.2, 148.95, 113.81, 5.73 !CRLF 3 ! FMFAC = 1.0 ! !END!

09000064817e49bb fc2_LNB 7/28/2014

## Revised **6/1/2010 EPA revised version of ENSR spreadsheet for case 3**  **fc3 - SCR Units 1-5, no LNB** new PM fine soil Filterable PM10 Condensable PM10 (CPM) Filterable PM fine total fine soil EC total H2SO4 organic H2SO4 HCl HF HCl + HFHCl+HF+ PmfineHCl+HF+

Pmfine Max Heat Input SO2 NOx H2SO4 NH3 PM coarsePM fine soil PM fine

EC inorganic

(SO4) organic

(SOA)Max Stack

Test MMBtu/hr (a) Btu/lb

(b) % wt.

(b) lb/MMBtu

(c) lb/hr lb/MMBtu (c) lb/hr lb/MMBtu (c) lb/hr Basis lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb mole/hrlb mole/hrlb mole/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/mmbtulb/mmbtulb/Mmbtu lb/hr lb/hr lb/mmbtu MMBtu/hrlb/MMBtulb/MMBtulb/MMBtulb/MMBtulb/MMBtulb/MMBtulb/MMBtulb/MMBtulb/MMBtulb/MMBtu

1 Bituminous Coal, 190 MW, PC Wall-Fired, Dry Bottom, Venturi Scrubber, Wet FGD LNB, OFA, SCR 80% 2,349 8,880 0.772 0.172 404.03 0.222 522.54 0.033 77.52 Stack Test 55.04 (d) 15.50 39.5 (d) 38.07 1.46 (f) 19.27 9.87 (g) 9.40 (i) 42.19 1.07 (j) 0.063 0.430 -0.37 (k) 0.00 (k) 8.44 0.31 (l) 8.74 8.57 73.18 0.00372 0 0 0 38.07 0.016 Unit 1 2,349 0.22 0.17 0.00372 0 0.0066 0.016 0.00062 0.00365 0.004 0.033

2 Bituminous Coal, 190 MW, PC Wall-Fired, Dry Bottom, Venturi Scrubber, Wet FGD LNB, OFA, SCR 80% 2,352 8,880 0.772 0.136 319.89 0.262 615.12 0.050 117.61 Stack Test 83.50 (d) 23.52 60.0 (d) 57.76 2.22 (f) 19.30 9.89 (g) 9.41 (i) 42.25 1.07 (j) 0.063 0.431 -0.37 (k) 0.00 (k) 8.45 0.31 (l) 8.76 8.58 101.67 0.00372 0 0 0 57.76 0.025 Unit 2 2,352 0.26 0.14 0.00372 0 0.01 0.025 0.00094 0.00365 0.004 0.050

3Bituminous Coal, 253 MW, PC Wall-Fired, Dry Bottom, Venturi Scrubber, Wet FGD LNB, OFA, SCR 80% 3,032 8,880 0.772 0.130 394.16 0.344 1,042.09 0.040 121.28 Stack Test 86.11 (d) 24.26 61.9 (d) 59.56 2.29 (f) 24.87 12.74 (g)12.13 (i) 54.46 1.38 (j) 0.081 0.555 -0.47 (k) 0.00 (k) 10.89 0.40 (l) 11.29 11.06 109.52 0.00372 0 0 0 59.56 0.020 Unit 3 3,032 0.34 0.13 0.00372 0 0.008 0.020 0.00075 0.00365 0.004 0.040

4Bituminous Coal, 818 MW, PC Cell Burner, Dry Bottom, Fabric Filter, Semi-Dry FGD LNB, OFA, SCR 80% 8,000 8,880 0.772 0.125 1,003.20 0.253 2,026.10 0.025 197.75 Stack Test 181.926 (e)77.12 104.81 (e)100.93 3.88 (f) 34.43 2.43 (h) 32.00 (i) 143.70 3.63 (j) 0.213 1.465 -1.25 (k) 0.00 (k) 2.08 0.21 (l) 2.29 2.24 216.21 0.00029 0 0 0 100.93 0.013 Unit 4 8,000 0.25 0.13 0.00029 0 0.0096 0.013 0.00048 0.00028 0.004 0.025

5Bituminous Coal, 818 MW, PC Cell Burner, Dry Bottom, Fabric Filter, Semi-Dry FGD LNB, OFA, SCR 80% 8,051 8,880 0.772 0.112 901.71 0.265 2,131.85 0.012 94.09 Stack Test 86.559 (e) 36.69 49.87 (e) 48.02 1.85 (f) 34.65 2.45 (h) 32.20 (i) 144.61 3.65 (j) 0.214 1.475 -1.26 (k) 0.00 (k) 2.09 0.21 (l) 2.30 2.25 121.06 0.00029 0 0 0 48.02 0.006 Unit 5 8,051 0.26 0.11 0.00029 0 0.0046 0.006 0.00023 0.00028 0.004 0.012

(a) Maximum heat input rate are based worst-case daily emissions for calendar years 2002 through 2006. EPA revised to take 2001 max for units 1, 3, 5 NOx Case 7 fc3_SCR fc3_SCR (b) Higher heating values and sulfur content are based on the average values for calendar years 2002 through 2006. 

### lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals **CALPUFF input lines** (d) For a dry bottom boiler fired with bituminous coal and equipped with a scrubber, total filterable PM10 is 71% of filterable PM and fine filterable PM10 is 51% of filterable PM based on AP-42, Table 1.1-6. Max Heat Input SO2 NOx H2SO4 NH3 PM coarsePM fine soil PM fine

EC inorganic

(SO4) organic

(SOA)Max Stack

Test (e) For a dry bottom boiler fired with bituminous coal and equipped with a bagouse, total filterable PM10 is 92% of filterable PM and fine filterable PM10 is 53% of filterable PM based on AP-42, Table 1.1-6. MMBtu/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr SO2 SO4 NOX HNO3 NO3 SOA PMF PMC EC Unit 1 2,349 522.54 404.03 8.74 0 15.50 38.07 1.46 8.57 9.40 77.52 Unit 1 522.54 8.57 404.03 0 0 9.40 38.07 15.50 1.46 1 ! SRCNAM = FCPP1 !CRLF 1 ! X = -1016.21601, -301.69621, 75.9, 1625.5, 6.47, 20.73, 323.15, 0, 522.54, 8.57, 404.03, CRLF 0, 0, 9.4, 38.07, 15.5, 1.46 !CRLF 1 ! FMFAC = 1.0 ! !END!

Unit 2 2,352 615.12 319.89 8.76 0 23.52 57.76 2.22 8.58 9.41 117.61 Unit 2 615.12 8.58 319.89 0 0 9.41 57.76 23.52 2.22 2 ! SRCNAM = FCPP2 !CRLF 2 ! X = -1016.21601, -301.69621, 75.9, 1625.5, 6.47, 20.73, 323.15, 0, 615.12, 8.58, 319.89, CRLF 0, 0, 9.41, 57.76, 23.52, 2.22 !CRLF 2 ! FMFAC = 1.0 ! !END!

Unit 3 3,032 1,042.09 394.16 11.29 0 24.26 59.56 2.29 11.06 12.13 121.28 Unit 3 1042.09 11.06 394.16 0 0 12.13 59.56 24.26 2.29 3 ! SRCNAM = FCPP3 !CRLF 3 ! X = -1016.19928, -301.77622, 76.2, 1625.27, 4.57, 23.77, 323.15, 0, 1042.09, 11.06, 394.16, CRLF 0, 0, 12.13, 59.56, 24.26, 2.29 !CRLF 3 ! FMFAC = 1.0 ! !END! Unit 4 8,000 2,026.10 1,003.20 2.29 0 77.12 100.93 3.88 2.24 32.00 197.75 Unit 4 2026.10 2.241003.20 0 0 32.00 100.93 77.12 3.88 4 ! SRCNAM = FCPP4 !CRLF 4 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, 2026.1, 2.24, 1003.2, CRLF 0, 0, 32, 100.93, 77.12, 3.88 !CRLF 4 ! FMFAC = 1.0 ! !END! (j) Ammonia slip is, on average, 0.75 ppmvd at 6% O2 for SCR per EPRI 2008. Unit 5 8,051 2,131.85 901.71 2.30 0 36.69 48.02 1.85 2.25 32.20 94.09 Unit 5 2131.85 2.25 901.71 0 0 32.20 48.02 36.69 1.85 5 ! SRCNAM = FCPP5 !CRLF 5 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, 2131.85, 2.25, 901.71, CRLF 0, 0, 32.2, 48.02, 36.69, 1.85 !CRLF 5 ! FMFAC = 1.0 ! !END! (k) 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. (l) Capture efficiency for ammonium sulfate/bisulfate particles is assumed to be 95% for a venturi scrubber and 99% for a fabric filter, respectively **Units 1 and 2 summed, unit3, and units 4 and 5 summed** NH3 0.75ppmvd at 6% O2

0.00045lb/MMBtu SO2 SO4 NOX HNO3 NO3 SOA PMF PMC EC unit 1 1.07lb/hr Units 1 & 21137.66 17.15 723.92 0.00 0.00 18.81 95.83 39.02 3.68 1 ! SRCNAM = FCPP12 !CRLF 1 ! X = -1016.21601, -301.69621, 75.9, 1625.5, 6.47, 20.73, 323.15, 0, 1137.66, 17.15, 723.92, CRLF 0, 0, 18.81, 95.83, 39.02, 3.68 !CRLF 1 ! FMFAC = 1.0 ! !END! unit 2 1.07lb/hr Unit 3 1042.09 11.06 394.16 0.00 0.00 12.13 59.56 24.26 2.29 2 ! SRCNAM = FCPP3 !CRLF 2 ! X = -1016.19928, -301.77622, 76.2, 1625.27, 4.57, 23.77, 323.15, 0, 1042.09, 11.06, 394.16, CRLF 0, 0, 12.13, 59.56, 24.26, 2.29 !CRLF 2 ! FMFAC = 1.0 ! !END! unit 3 1.38lb/hr Units 4 & 54157.95 4.491904.91 0.00 0.00 64.20 148.95 113.81 5.73 3 ! SRCNAM = FCPP45 !CRLF 3 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, 4157.95, 4.49, 1904.91, CRLF 0, 0, 64.2, 148.95, 113.81, 5.73 !CRLF 3 ! FMFAC = 1.0 ! !END! unit 4 3.63lb/hr unit 5 3.65lb/hr Revisions 4/5/10 Set HCl and HF to zero - so Pmfine unchanged from Aecom values ANPR included a 20% compliance margin in NOx emission rate, but removed here since it likely double counts (already relies on 24-hour max) Use SO2 to SO3 conversion of 0.6% (average of 0.5% and 0.7% with additional catalyst layer) 

## APS Four Corners Plant - BART Determination Modeling **NOx Control Case "fc3"**

Total Effective H2SO4 Condensable PM10 Max. Heat Input Unit Description New NOx BART Controls Percent

NOx Control

(i) For pulverized coal-fired boilers with an FGD system, total condensable organic PM10 emissions factor is 0.004 lb/MMBtu based on AP-42, Table 1.1-5. (f) 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. Total Effective SO4 for Modeling

(c) Baseline NOx, SO2 and filterable PM emissions are based worst-case daily emissions received on March 2, 2007 and revised April 26, 2007. EPA Revised to take 2001 max NOx for units 1, 2, 3, 5 Total H2SO4 before NH3 interaction total coarse Maximum SO2 Emissions Maximum Filterable PM Emissions Filterable PM10 Higher Heating Value Fuel Sulfur

Content Maximum NOx

Emissions Fine

(g) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants," EPRI, Technical Update, March 2008 and Hardman et al., 1998. For coal-fired boilers, H2SO4 emissions are determined from "(Q)(98.06/64.04)(F1+S2)(F2)" where Q is the uncontrolled SO2 emission rate (in lb/hr, calculated from heat rate, fuel S content, and 95% of fuel sulfur converted to SO2), F1 is the fuel factor (0.00111 for western bituminous coal), and F2 is the product of the control factors (0.9 for an air preheater, 0.65 for a venturi scrubber, and 0.10 for a baghouse or cold-side wet ESP). EPA revised air preheater factor to 0.36 based on EPRI 2010 update. (h) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants," EPRI, Technical Update, March 2008 and Hardman et al., 1998. For coal-fired boilers, H2SO4 emissions are determined from "(Q)(98.06/64.04)(F1+S2)(F2)" where Q is the uncontrolled SO2 emission rate (in lb/hr, calculated from heat rate, fuel S content, and 95% of fuel sulfur converted to SO2), F1 is the fuel factor (0.00111 for western bituminous coal), and F2 is the product of the control factors (0.9 for an air preheater, 0.65 for a venturi scrubber, and 0.10 for a baghouse or cold-side wet ESP). EPA revised air preheater factor to 0.36 based on EPRI 2010 update. Total PM10 NH3 Slip (NH4)2SO4 /NH4HSO4 (as H2SO4) H2SO4 Emitted NH3 H2SO4 Excess NH3 (Slip)

09000064817e49bb fc3 SCR 7/28/2014

# Revised **6/1/2010**

**SCR + LNB (LNB + additional 80% NOx control**

MMBtu/hr (a) Btu/lb

(b) % wt.

(b)

1Bituminous Coal, 190 MW, PC Wall-Fired, Dry

Bottom, Venturi Scrubber, Wet FGD LNB,SCR 80% 2,349 8,880 0.772

2Bituminous Coal, 190 MW, PC Wall-Fired, Dry

Bottom, Venturi Scrubber, Wet FGD LNB,SCR 80% 2,352 8,880 0.772

3Bituminous Coal, 253 MW, PC Wall-Fired, Dry

Bottom, Venturi Scrubber, Wet FGD LNB, OFA, SCR 80% 3,032 8,880 0.772

4Bituminous Coal, 818 MW, PC Cell Burner, Dry

Bottom, Fabric Filter, Semi-Dry

FGD LNB, OFA,

SCR 80% 8,000 8,880 0.772

5Bituminous Coal, 818 MW, PC Cell Burner, Dry

Bottom, Fabric Filter, Semi-Dry

FGD LNB, OFA,

SCR 80% 8,051 8,880 0.772

(a) Maximum heat input rate are based worst-case daily emissions for calendar years 2002 through 2006. EPA revised to take 2001 max for units 1, 3, 5 (b) Higher heating values and sulfur content are based on the average values for calendar years 2002 through 2006. (d) For a dry

bottom boiler fired with bituminous coal and equipped with a scrubber, total filterable PM10 is 71% of filterable PM and fine filterable PM10 is 51% of filterable PM based on AP-42, Table 1.1-6. (e) For a dry

bottom boiler fired with bituminous coal and equipped with a bagouse, total filterable PM10 is 92% of filterable PM and fine filterable PM10 is 53% of filterable PM based on AP-42, Table 1.1-6.

(j) Ammonia slip is, on average, 0.75 ppmvd at 6% O2 for SCR per EPRI 2008. (k) 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. (l) Capture efficiency

for ammonium sulfate/bisulfate particles is assumed to be 95% for a venturi scrubber and 99% for a fabric filter, respectively Unit Description New NOx BART ControlsPercent NOx

Control Max. Heat

Input Higher

Heating Value Fuel Sulfur

Content

(c) Baseline NOx, SO2 and filterable PM emissions are based worst-case daily emissions received on March 2, 2007 and revised April 26, 2007. EPA Revised to take 2001 max NOx for units 1, 2, 3, 5

(f) 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”, WilliamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002.

(i) For pulverized coal-fired boilers with an FGD system, total condensable organic PM10 emissions factor is 0.004 lb/MMBtu based on AP-42, Table 1.1-5. (g) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants," EPRI, Technical Update, March 2008 and Hardman et al., 1998. For coal-fired boilers, H2SO4 emissions are determined from "(Q)(98.06/64.04)(F1+S2)(F2)" where Q is the uncontrolled SO2 emission rate (in lb/hr, calculated from heat rate, fuel S content, and 95% of fuel sulfur converted to SO2), F1 is the fuel factor (0.00111 for western bituminous coal), and F2 is the product of the control factors ( preheater factor to 0.36 based on EPRI 2010 update. (h) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants," EPRI, Technical Update, March 2008 and Hardman et al., 1998. For coal-fired boilers, H2SO4 emissions are determined from "(Q)(98.06/64.04)(F1+S2)(F2)" where Q is the uncontrolled SO2 emission rate (in lb/hr, calculated from heat rate, fuel S content, and 95% of fuel sulfur converted to SO2), F1 is the fuel factor (0.00111 for western bituminous coal), and F2 is the product of the control factors ( preheater factor to 0.36 based on EPRI 2010 update.

# NH3 0.75ppmvd at 6% O2 0.00045lb/MMBtu unit 1 1.07lb/hr unit 2 1.07lb/hr unit 3 1.38lb/hr unit 4 3.63lb/hr unit 5 3.65lb/hr Revisions 4/5/10 Set HCl and HF to zero - so Pmfine unchanged from Aecom values Different from fc3 - assumes LNB or LNB/OFA will be effective ANPR included a 20% compliance margin in NOx emission rate, but removed here since it likely double counts (already relies on 24-hour max) Use SO2 to SO3 conversion of 0.6% (average of 0.5% and 0.7% with additional catalyst layer)

# lb/MMBtu

(c) lb/hr lb/MMBtu (c) lb/hr lb/MMBtu (c) lb/hr Basis lb/hr lb/hr

0.094 221.81 0.222 522.54 0.033 77.52 Stack Test 55.04 (d) 15.50

0.091 214.65 0.262 615.12 0.050 117.61 Stack Test 83.50 (d) 23.52

0.073 220.73 0.344 1,042.09 0.040 121.28 Stack Test 86.11 (d) 24.26

0.089 712.27 0.253 2,026.10 0.025 197.75 Stack Test 181.926 (e) 77.12

0.080 640.22 0.265 2,131.85 0.012 94.09 Stack Test 86.559 (e) 36.69

(a) Maximum heat input rate are based worst-case daily emissions for calendar years 2002 through 2006. EPA revised to take 2001 max for units 1, 3, 5 (b) Higher heating values and sulfur content are based on the average values for calendar years 2002 through 2006. (d) For a dry

bottom boiler fired with bituminous coal and equipped with a scrubber, total filterable PM10 is 71% of filterable PM and fine filterable PM10 is 51% of filterable PM based on AP-42, Table 1.1-6. (e) For a dry

bottom boiler fired with bituminous coal and equipped with a bagouse, total filterable PM10 is 92% of filterable PM and fine filterable PM10 is 53% of filterable PM based on AP-42, Table 1.1-6.

(k) 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. (l) Capture efficiency

for ammonium sulfate/bisulfate particles is assumed to be 95% for a venturi scrubber and 99% for a fabric filter, respectively 

# AP**S Four Corners Plant - BA RT Determination Modeling** 

**fc4 - w as not included in A** **NPR**

Maximum NOx Emissions total coarse

(c) Baseline NOx, SO2 and filterable PM emissions are based worst-case daily emissions received on March 2, 2007 and revised April 26, 2007. EPA Revised to take 2001 max NOx for units 1, 2, 3, 5 Maximum SO2 Emissions Maximum Filterable PM Emissions Filterable PM10

(f) 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”, WilliamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046,

(i) For pulverized coal-fired boilers with an FGD system, total condensable organic PM10 emissions factor is 0.004 lb/MMBtu based on AP-42, Table 1.1-5. (g) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants," EPRI, Technical Update, March 2008 and Hardman et al., 1998. For coal-fired boilers, H2SO4 emissions are determined from "(Q)(98.06/64.04)(F1+S2)(F2)" where Q is the uncontrolled SO2 emission rate (in lb/hr, calculated from heat rate, fuel S content, and 95% of fuel sulfur converted to SO2), F1 is the fuel factor (0.00111 for western bituminous coal), and F2 is the product of the control factors (0.9 for an air preheater (h) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants," EPRI, Technical Update, March 2008 and Hardman et al., 1998. For coal-fired boilers, H2SO4 emissions are determined from "(Q)(98.06/64.04)(F1+S2)(F2)" where Q is the uncontrolled SO2 emission rate (in lb/hr, calculated from heat rate, fuel S content, and 95% of fuel sulfur converted to SO2), F1 is the fuel factor (0.00111 for western bituminous coal), and F2 is the product of the control factors (0.9 for an air preheater

# ANPR included a 20% compliance margin in NOx emission rate, but removed here since it likely double counts (already relies on 24-hour max)

# fine total fine soil EC total H2SO4 organic

lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb mole/hr

39.5 (d) 38.07 1.46 (f) 19.27 9.87 (g) 9.40 (i) 42.19 1.07 (j) 0.063

60.0 (d) 57.76 2.22 (f) 19.30 9.89 (g) 9.41 (i) 42.25 1.07 (j) 0.063

61.9 (d) 59.56 2.29 (f) 24.87 12.74 (g)12.13 (i) 54.46 1.38 (j) 0.081

104.81 (e) 100.93 3.88 (f) 34.43 2.43 (h) 32.00 (i) 143.70 3.63 (j) 0.213

49.87 (e) 48.02 1.85 (f) 34.65 2.45 (h) 32.20 (i) 144.61 3.65 (j) 0.214

(d) For a dry

bottom boiler fired with bituminous coal and equipped with a scrubber, total filterable PM10 is 71% of filterable PM and fine filterable PM10 is 51% of filterable PM based on AP-42, Table 1.1-6. (e) For a dry

bottom boiler fired with bituminous coal and equipped with a bagouse, total filterable PM10 is 92% of filterable PM and fine filterable PM10 is 53% of filterable PM based on AP-42, Table 1.1-6. Fine NH3 Filterable PM10 Condensable PM10 Total H2SO4 before NH3 interaction

(f) 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”, WilliamBattye and Kathy Boyer, EPA Contract No. 68-D-98-046, NH3 Slip

(g) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants," EPRI, Technical Update, March 2008 and Hardman et al., 1998. For coal-fired boilers, H2SO4 emissions are determined from "(Q)(98.06/64.04)(F1+S2)(F2)" where Q is the uncontrolled SO2 emission rate 0.9 for an air preheater, 0.65 for a venturi scrubber, and 0.10 for a baghouse or cold-side wet ESP). EPA revised air (h) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants," EPRI, Technical Update, March 2008 and Hardman et al., 1998. For coal-fired boilers, H2SO4 emissions are determined from "(Q)(98.06/64.04)(F1+S2)(F2)" where Q is the uncontrolled SO2 emission rate 0.9 for an air preheater, 0.65 for a venturi scrubber, and 0.10 for a baghouse or cold-side wet ESP). EPA revised air

# H2SO4

lb mole/hrlb mole/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/mmbtu

0.430 -0.37 (k) 0.00 (k) 8.44 0.31 (l) 8.74 8.57 73.18 0.00372

0.431 -0.37 (k) 0.00 (k) 8.45 0.31 (l) 8.76 8.58 101.67 0.00372

0.555 -0.47 (k) 0.00 (k) 10.89 0.40 (l) 11.29 11.06 109.52 0.00372

1.465 -1.25 (k) 0.00 (k) 2.08 0.21 (l) 2.29 2.24 216.21 0.00029

1.475 -1.26 (k) 0.00 (k) 2.09 0.21 (l) 2.30 2.25 121.06 0.00029 Total PM10 H2SO4 Excess NH3 (Slip) H2SO4 Emitted (NH4)2SO4

/NH4HSO4 (as H2SO4) 

# Total

Effective H2SO4 Total

Effective SO4 for Modeling

# fc4 - SCR Units 1-5, LNB new PM fine soil HCl HF HCl + HFHCl+HF+ PmfineHCl+HF+

Pmfine Max Heat Input lb/mmbtulb/Mmbtu lb/hr lb/hr lb/mmbtu MMBtu/hr

0 0 0 38.07 0.016 Unit 1 2,349

0 0 0 57.76 0.025 Unit 2 2,352

0 0 0 59.56 0.020 Unit 3 3,032

0 0 0 100.93 0.013 Unit 4 8,000

0 0 0 48.02 0.006 Unit 5 8,051

fc4

Max Heat

Input MMBtu/hr Unit 1 2,349

Unit 2 2,352

Unit 3 3,032 Unit 4 8,000 Unit 5 8,051

# fc4 - SCR Units 1-5, LNB Filterable PM10 Condensable PM10 (CPM) Filterable PM SO2 NOx H2SO4 NH3 PM coarsePM fine soil PM fine

EC inorganic

(SO4) organic

(SOA)Max Stack

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

0.22 0.09 0.00372 0 0.0066 0.016 0.00062 0.00365 0.004 0.033

0.26 0.09 0.00372 0 0.01 0.025 0.00094 0.00365 0.004 0.050

0.34 0.07 0.00372 0 0.008 0.020 0.00075 0.00365 0.004 0.040

0.25 0.09 0.00029 0 0.0096 0.013 0.00048 0.00028 0.004 0.025

0.26 0.08 0.00029 0 0.0046 0.006 0.00023 0.00028 0.004 0.012

SO2 NOx H2SO4 NH3 PM coarsePM 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 lb/hr lb/hr 522.54 221.81 8.74 0 15.50 38.07 1.46 8.57 9.40 77.52

615.12 214.65 8.76 0 23.52 57.76 2.22 8.58 9.41 117.61

1,042.09 220.73 11.29 0 24.26 59.56 2.29 11.06 12.13 121.28 2,026.10 712.27 2.29 0 77.12 100.93 3.88 2.24 32.00 197.75 2,131.85 640.22 2.30 0 36.69 48.02 1.85 2.25 32.20 94.09

# Filterable PM

fc4



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

SO2 SO4 NOX HNO3 NO3 SOA PMF PMC Unit 1 522.54 8.57 221.81 0 0 9.40 38.07 15.50

Unit 2 615.12 8.58 214.65 0 0 9.41 57.76 23.52

Unit 3 1042.09 11.06 220.73 0 0 12.13 59.56 24.26 Unit 4 2026.10 2.24 712.27 0 0 32.00 100.93 77.12 Unit 5 2131.85 2.25 640.22 0 0 32.20 48.02 36.69

# Units 1 and 2 summed, unit3, and units 4 and 5 summed
SO2 SO4 NOX HNO3 NO3 SOA PMF PMC Units 1 & 21137.66 17.15 436.46 0.00 0.00 18.81 95.83 39.02 Unit 3 1042.09 11.06 220.73 0.00 0.00 12.13 59.56 24.26 Units 4 & 54157.95 4.491352.49 0.00 0.00 64.20 148.95 113.81

# fc4 

# CALPUFF input lines

EC1.46 1 ! SRCNAM = FCPP1 !CRLF 1 ! X = -1016.21601, -301.69621, 75.9, 1625.5, 6.47, 20.73, 323.15, 0, 522.54, 8.57, 221.81, CRLF 0, 0, 9.4, 38.07, 15.5, 1.46 !CRLF 1 ! FMFAC = 1.0 ! !END!

2.22 2 ! SRCNAM = FCPP2 !CRLF 2 ! X = -1016.21601, -301.69621, 75.9, 1625.5, 6.47, 20.73, 323.15, 0, 615.12, 8.58, 214.65, CRLF 0, 0, 9.41, 57.76, 23.52, 2.22 !CRLF 2 ! FMFAC = 1.0 ! !END!

2.29 3 ! SRCNAM = FCPP3 !CRLF 3 ! X = -1016.19928, -301.77622, 76.2, 1625.27, 4.57, 23.77, 323.15, 0, 1042.09, 11.06, 220.73, CRLF 0, 0, 12.13, 59.56, 24.26, 2.29 !CRLF 3 ! FMFAC = 1.0 ! !END! 3.88 4 ! SRCNAM = FCPP4 !CRLF 4 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, 2026.1, 2.24, 712.27, CRLF 0, 0, 32, 100.93, 77.12, 3.88 !CRLF 4 ! FMFAC = 1.0 ! !END! 1.85 5 ! SRCNAM = FCPP5 !CRLF 5 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, 2131.85, 2.25, 640.22, CRLF 0, 0, 32.2, 48.02, 36.69, 1.85 !CRLF 5 ! FMFAC = 1.0 ! !END!

# EC3.68 1 ! SRCNAM = FCPP12 !CRLF 1 ! X = -1016.21601, -301.69621, 75.9, 1625.5, 6.47, 20.73, 323.15, 0, 1137.66, 17.15, 436.46, CRLF 0, 0, 18.81, 95.83, 39.02, 3.68 !CRLF 1 ! FMFAC = 1.0 ! !END!

2.29 2 ! SRCNAM = FCPP3 !CRLF 2 ! X = -1016.19928, -301.77622, 76.2, 1625.27, 4.57, 23.77, 323.15, 0, 1042.09, 11.06, 220.73, CRLF 0, 0, 12.13, 59.56, 24.26, 2.29 !CRLF 2 ! FMFAC = 1.0 ! !END! 5.73 3 ! SRCNAM = FCPP45 !CRLF 3 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, 4157.95, 4.49, 1352.49, CRLF 0, 0, 64.2, 148.95, 113.81, 5.73 !CRLF 3 ! FMFAC = 1.0 ! !END!

# 1 ! SRCNAM = FCPP1 !CRLF 1 ! X = -1016.21601, -301.69621, 75.9, 1625.5, 6.47, 20.73, 323.15, 0, 522.54, 8.57, 221.81, CRLF 0, 0, 9.4, 38.07, 15.5, 1.46 !CRLF 1 ! FMFAC = 1.0 ! !END!
2 ! SRCNAM = FCPP2 !CRLF 2 ! X = -1016.21601, -301.69621, 75.9, 1625.5, 6.47, 20.73, 323.15, 0, 615.12, 8.58, 214.65, CRLF 0, 0, 9.41, 57.76, 23.52, 2.22 !CRLF 2 ! FMFAC = 1.0 ! !END!

3 ! SRCNAM = FCPP3 !CRLF 3 ! X = -1016.19928, -301.77622, 76.2, 1625.27, 4.57, 23.77, 323.15, 0, 1042.09, 11.06, 220.73, CRLF 0, 0, 12.13, 59.56, 24.26, 2.29 !CRLF 3 ! FMFAC = 1.0 ! !END! 4 ! SRCNAM = FCPP4 !CRLF 4 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, 2026.1, 2.24, 712.27, CRLF 0, 0, 32, 100.93, 77.12, 3.88 !CRLF 4 ! FMFAC = 1.0 ! !END! 5 ! SRCNAM = FCPP5 !CRLF 5 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, 2131.85, 2.25, 640.22, CRLF 0, 0, 32.2, 48.02, 36.69, 1.85 !CRLF 5 ! FMFAC = 1.0 ! !END!

# 1 ! SRCNAM = FCPP12 !CRLF 1 ! X = -1016.21601, -301.69621, 75.9, 1625.5, 6.47, 20.73, 323.15, 0, 1137.66, 17.15, 436.46, CRLF 0, 0, 18.81, 95.83, 39.02, 3.68 !CRLF 1 ! FMFAC = 1.0 ! !END! 2 ! SRCNAM = FCPP3 !CRLF 2 ! X = -1016.19928, -301.77622, 76.2, 1625.27, 4.57, 23.77, 323.15, 0, 1042.09, 11.06, 220.73, CRLF 0, 0, 12.13, 59.56, 24.26, 2.29 !CRLF 2 ! FMFAC = 1.0 ! !END! 3 ! SRCNAM = FCPP45 !CRLF 3 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, 4157.95, 4.49, 1352.49, CRLF 0, 0, 64.2, 148.95, 113.81, 5.73 !CRLF 3 ! FMFAC = 1.0 ! !END!

# 1 ! SRCNAM = FCPP1 !CRLF 1 ! X = -1016.21601, -301.69621, 75.9, 1625.5, 6.47, 20.73, 323.15, 0, 522.54, 8.57, 221.81, CRLF 0, 0, 9.4, 38.07, 15.5, 1.46 !CRLF 1 ! FMFAC = 1.0 ! !END!
2 ! SRCNAM = FCPP2 !CRLF 2 ! X = -1016.21601, -301.69621, 75.9, 1625.5, 6.47, 20.73, 323.15, 0, 615.12, 8.58, 214.65, CRLF 0, 0, 9.41, 57.76, 23.52, 2.22 !CRLF 2 ! FMFAC = 1.0 ! !END!

3 ! SRCNAM = FCPP3 !CRLF 3 ! X = -1016.19928, -301.77622, 76.2, 1625.27, 4.57, 23.77, 323.15, 0, 1042.09, 11.06, 220.73, CRLF 0, 0, 12.13, 59.56, 24.26, 2.29 !CRLF 3 ! FMFAC = 1.0 ! !END! 4 ! SRCNAM = FCPP4 !CRLF 4 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, 2026.1, 2.24, 712.27, CRLF 0, 0, 32, 100.93, 77.12, 3.88 !CRLF 4 ! FMFAC = 1.0 ! !END! 5 ! SRCNAM = FCPP5 !CRLF 5 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, 2131.85, 2.25, 640.22, CRLF 0, 0, 32.2, 48.02, 36.69, 1.85 !CRLF 5 ! FMFAC = 1.0 ! !END!

# 1 ! SRCNAM = FCPP12 !CRLF 1 ! X = -1016.21601, -301.69621, 75.9, 1625.5, 6.47, 20.73, 323.15, 0, 1137.66, 17.15, 436.46, CRLF 0, 0, 18.81, 95.83, 39.02, 3.68 !CRLF 1 ! FMFAC = 1.0 ! !END! 2 ! SRCNAM = FCPP3 !CRLF 2 ! X = -1016.19928, -301.77622, 76.2, 1625.27, 4.57, 23.77, 323.15, 0, 1042.09, 11.06, 220.73, CRLF 0, 0, 12.13, 59.56, 24.26, 2.29 !CRLF 2 ! FMFAC = 1.0 ! !END! 3 ! SRCNAM = FCPP45 !CRLF 3 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, 4157.95, 4.49, 1352.49, CRLF 0, 0, 64.2, 148.95, 113.81, 5.73 !CRLF 3 ! FMFAC = 1.0 ! !END!

# CA**LPUFF inputs**

Point source inputs for CALPUFF group 13b, other than emissions These are combined with emissions in the sheets for particular control cases to get the final CALPUFF lines

**Four Corners Power Plant, all stacks separate**

SRCNAMSource No. X Coordinat e (km) Y

Coordinat e (km) Stack

Height (m) FCPP1 1 -1016.22-301.696 75.9 FCPP2 2 -1016.22-301.696 75.9 FCPP3 3 -1016.2-301.776 76.2 FCPP4 4 -1015.87-302.166 93.73 FCPP5 5 -1015.87-302.166 93.73
**Four Corners Power Plant, combined stacks 1 & 2, and 4 & 5**

SRCNAMSource

No. X Coordinat e (km) Y

Coordinat e (km) Stack

Height (m) FCPP12 1 -1016.22-301.696 75.9 FCPP3 2 -1016.2-301.776 76.2 FCPP45 3 -1015.87-302.166 93.73

# These are combined with emissions in the sheets for particular control cases to get the final CALPUFF lines **CA LPUFF line parts**  descriptioncell name separator sep Build model input line line ends lend Line 1 srcnam Line 2 parms Line 3 fmfac

Base Elevation (m) Stack

Diameter (m) Exit Vel.

(m/s) Exit

Temp. (deg. K)Bldg.

Dwash 1625.5 6.47 20.73 323.15 0 1625.5 6.47 20.73 323.15 0 1625.27 4.57 23.77 323.15 0 1631.29 12.28 19.21 325.93 0 1631.29 12.28 19.21 325.93 0

Base Elevation (m) Stack

Diameter (m) Exit Vel.

(m/s) Exit

Temp. (deg. K)Bldg.

Dwash 1625.5 6.47 20.73 323.15 0 1625.27 4.57 23.77 323.15 0 1631.29 12.28 19.21 325.93 0

# contents

, !CRLF ! SRCNAM = ! X = ! FMFAC = 1.0 ! !END!

prefix for CALPUFF line suffix for CALPUFF line 1 !SRCNAM = FCPP1 !CRLF 1 ! X = -1016.21601, -301.69621, 75.9, 1625.5, 6.47, 20.73, 323.15, 0, !CRLF 1 ! FMFAC = 1.0 ! !END! 2 !SRCNAM = FCPP2 !CRLF 2 ! X = -1016.21601, -301.69621, 75.9, 1625.5, 6.47, 20.73, 323.15, 0, !CRLF 2 ! FMFAC = 1.0 ! !END! 3 !SRCNAM = FCPP3 !CRLF 3 ! X = -1016.19928, -301.77622, 76.2, 1625.27, 4.57, 23.77, 323.15, 0, !CRLF 3 ! FMFAC = 1.0 ! !END! 4 !SRCNAM = FCPP4 !CRLF 4 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, !CRLF 4 ! FMFAC = 1.0 ! !END! 5 !SRCNAM = FCPP5 !CRLF 5 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, !CRLF 5 ! FMFAC = 1.0 ! !END!

prefix for CALPUFF line 1 !SRCNAM = FCPP12 !CRLF 1 ! X = -1016.21601, -301.69621, 75.9, 1625.5, 6.47, 20.73, 323.15, 0, !CRLF 1 ! FMFAC = 1.0 ! !END! 2 !SRCNAM = FCPP3 !CRLF 2 ! X = -1016.19928, -301.77622, 76.2, 1625.27, 4.57, 23.77, 323.15, 0, !CRLF 2 ! FMFAC = 1.0 ! !END! 3 !SRCNAM = FCPP45 !CRLF 3 ! X = -1015.87016, -302.16603, 93.73, 1631.29, 12.28, 19.21, 325.93, 0, !CRLF 3 ! FMFAC = 1.0 ! !END!

# Annual Average Emissions

**Unit 1** 

# Heat Input **Capacity Factor SO2**  **SO2 NOx**  **PM H2SO4**  **H2SO4 (mmBtu)**  **(%) (lb/MMBtu)**  **(Tons) (Tons)**  **(tons) (lb/MMBtu)**  **(Tons)** 2002 1 13,740,127 78.92 N/A N/A 0.767 5,269 0.033 226.7 5.09E-04 3.5 2003 1 14,616,287 87.31 N/A N/A 0.768 5,613 0.023 168.1 5.47E-04 4 2004 1 14,986,804 90.19 N/A N/A 0.792 5,935 0.02 149.9 5.60E-04 4.2 2005 1 13,764,408 85.38 0.128 879.8 0.782 5,382 0.028 192.7 5.96E-04 4.1 2006 1 15,708,239 96.71 0.116 910.9 0.804 6,315 0.021 164.9 1.34E-03 10.5 Average 14,563,173 0.122 0.783 0.025 7.10E-04 5.26

**Unit 2** 

# Heat Input **Capacity Factor SO2**  **SO2 NOx**  **PM H2SO4**  **H2SO4 (mmBtu)**  **(%) (lb/MMBtu)**  **(Tons) (Tons)**  **(tons) (lb/MMBtu)**  **(Tons)** 2002 2 16,632,804 88.31 N/A N/A 0.614 5,106 0.022 183 4.69E-04 3.9 2003 2 14,138,653 85.3 N/A N/A 0.618 4,369 0.027 190.9 5.38E-04 3.8 2004 2 13,261,038 80.66 N/A N/A 0.663 4,396 0.023 152.5 5.58E-04 3.7 2005 2 15,546,054 95.15 0.136 1,054.70 0.654 5,084 0.05 388.7 5.92E-04 4.6 2006 2 15,272,703 93.61 0.118 901.7 0.653 4,987 0.024 183.3 1.32E-03 10.1 Average 14,970,250 0.127 0.640 0.029 6.96E-04 5.22
**Unit 3** 

# Heat Input **Capacity Factor SO2**  **SO2 NOx**  **PM H2SO4**  **H2SO4 (mmBtu)**  **(%) (lb/MMBtu)**  **(Tons) (Tons)**  **(tons) (lb/MMBtu)**  **(Tons)** 2002 3 19,873,581 88.58 N/A N/A 0.570 5,664 0.04 397.5 5.03E-04 5 2003 3 17,341,579 76.34 N/A N/A 0.578 5,012 0.026 225.4 5.07E-04 4.4 2004 3 20,819,150 92.59 N/A N/A 0.600 6,246 0.023 239.4 5.19E-04 5.4 2005 3 20,865,668 91.75 0.150 1,566.60 0.584 6,093 0.039 406.9 5.56E-04 5.8 2006 3 17,101,624 72.29 0.159 1,357.50 0.602 5,148 0.018 153.9 1.18E-03 10.1 Average 19,200,320 0.154 0.587 0.029 6.53E-04 6.14
**Unit 4** 

# Heat Input **Capacity Factor SO2**  **SO2 NOx**  **PM H2SO4**  **H2SO4 (mmBtu)**  **(%) (lb/MMBtu)**  **(Tons) (Tons)**  **(tons) (lb/MMBtu)**  **(Tons)** 2002 4 57,787,846 88.01 N/A N/A 0.566 16,354 0.015 433.4 4.15E-05 1.2 2003 4 56,712,865 91.76 N/A N/A 0.565 16,021 0.007 198.5 4.58E-05 1.3 2004 4 42,188,456 69.22 N/A N/A 0.464 9,788 0.004 84.4 4.74E-05 1 2005 4 54,882,182 89.01 0.165 4,538.00 0.458 12,568 0.018 493.9 6.56E-05 1.8 2006 4 56,476,068 90.08 0.209 5,901.10 0.488 13,780 0.025 706 1.49E-04 4.2 Average 53,609,483 0.187 0.508 0.014 6.98E-05 1.9
**Unit 5** 

# Heat Input **Capacity Factor SO2**  **SO2 NOx**  **PM H2SO4**  **H2SO4 (mmBtu)**  **(%) (lb/MMBtu)**  **(Tons) (Tons)**  **(tons) (lb/MMBtu)**  **(Tons)** 2002 5 37,592,636 58.19 N/A N/A 0.450 8,458 0.011 206.8 4.26E-05 0.8 2003 5 56,065,980 87.76 N/A N/A 0.484 13,568 0.012 336.4 4.28E-05 1.2 **Year Unit**  **NOx (lb/mmBtu)** 

**Year Unit**  **NOx (lb/mmBtu)** 

**Year Unit**  **Year Unit**  **NOx (lb/mmBtu)**  **Year Unit**  **NOx (lb/mmBtu)**  **PM (lb/mmBtu)** 

**PM (lb/mmBtu)** 

**NOx (lb/mmBtu)**  **PM (lb/mmBtu)**  **PM (lb/mmBtu)** 

**PM (lb/mmBtu)** 

09000064817e49bb

# 2004 5 56,059,669 94.57 N/A N/A 0.495 13,875 0.004 112.1 4.99E-05 1.4 2005 5 51,267,335 83.14 0.176 4,515.30 0.472 12,099 0.012 307.6 6.63E-05 1.7 2006 5 55,280,458 88.64 0.221 6,121.20 0.498 13,765 0.009 248.8 1.48E-04 4.1 Average 51,253,216 0.199 0.480 0.010 7.00E-05 1.84 **Average Emissions Unit**  **SO2 NOx**  **PM H2SO4** 

**(lb/MMBtu) (lb/MMBtu)**  **(lb/MMBtu) (lb/MMBtu)**  1 0.154 0.587 0.029 6.53E-04 2 0.127 0.640 0.029 6.96E-04 3 0.154 0.587 0.029 6.53E-04 4 0.187 0.508 0.014 6.98E-05 5 0.199 0.480 0.010 7.00E-05 **Worst-Case Daily Emissions**

**Heat Input Rate Unit**  **(MMBtu/day) (lb/day)**  **lb/MMBtu (lb/day)**  **lb/MMBtu (lb/day)**  **lb/MMBtu** 1 50,079 44,192.90 0.882 11,140.10 0.222 1,502.40 0.030 2 56,452 37,623.90 0.666 14,762.80 0.262 2,339.10 0.041 3 69,498 46,229.60 0.665 23,886.20 0.344 2,585.20 0.037 4 192,001 120,383.50 0.627 48,626.50 0.253 4,745.90 0.025 5 193,125 106,657.00 0.552 51,138.30 0.265 2,256.90 0.012

previous value was a typo previous value was a SUSD day previous value was a SUSD day 193,195 

# 11,165.60 2,279.00 **SUSD**= START UP, SHUT DOWN 655046.082

464.1708333 615.1166667 995.2583333 2026.104167 2130.7625 

# NOx Emissions **SO2 Emissions PM Emissions** 

09000064817e49bb

# Four Corners **lb Sulfur/Ton Coal % Sulfur**  **MMBtu/Ton Coal** 2000 15.58 0.779 18.00 2001 15.46 0.773 17.97 2002 15.28 0.764 17.74 2003 15.46 0.773 17.56 2004 15.04 0.752 17.74 2005 15.55 0.778 17.89 2006 15.90 0.795 17.87 2007 15.81 0.791 17.91 2008 15.60 0.780 17.91 2009 15.50 0.775 17.89 2010 15.50 0.775 17.82 2011 15.70 0.785 17.98 2012 16.93 0.847 18.01 2013 16.00 0.800 18.01 2014 16.10 0.805 17.89 2015 16.90 0.845 17.76 2016 17.00 0.850 17.78 **2002-2006 A**

**verage 15.446**  **0.772 17.760**  **2011-2016 A**

**verage 16.438**  **0.822 17.905**  **Year**

# Btu/lb Coal **lbs Sulfur / MMBtu lbs SO** **2**

# / MMBtu

9,000 0.87 1.731 8,985 0.86 1.721 8,870 0.86 1.723 8,780 0.88 1.761 8,870 0.85 1.696 8,945 0.87 1.738 8,935 0.89 1.780 8,955 0.88 1.765 8,955 0.87 1.742 8,945 0.87 1.733 8,910 0.87 1.740 8,990 0.87 1.746 9,005 0.94 1.880 9,005 0.89 1.777 8,945 0.90 1.800 8,880 0.95 1.903 8,890 0.96 1.912 **8,880 0.870**  **1.739 8,953**  **0.918 1.836**