# This spreadsheet is intended to display "major sources" of Sulfur Dioxide (SO2) Emissions located in the three RH 309 states as projected for Calendar Year 2018 It is broken down into 3 subgroups: 1) Existing Electrical Generating Units (EGU's) 2) Permitted or Future Electrical Generating Units (EGU's) ... & ... 3) Other Industrial Point Sources (Non-EGU's)

EGU's The Methodology for projecting existing EGU's into the future involves the following steps: 1) the electricity production (MW's) for each individual unit at a plant was determined from the Energy Information Administration [EIA] (data available for 2002-05) 2) the electricity generation design maximum capacity (MW's) was determined for each individual unit from EIA data 3) an operating Capacity Factor was determined by dividing the year specific production by the design maximum capacity of the each individual plant unit 4) all individual units were assumed to be operating at 85% capacity in 2018 (unless they were already operating above this level) 5) the Growth Ratio necessary to achieve 85% capacity was determined by dividing 0.85 by the Capacity Factor for each individual plant unit from Step 3 (averaged over four years) 6) a Current Year Emission Factor (lb SO2/MM Btu) was calculated for the latest year of available EIA data (2006), using the actual reported emissions (tons SO2) for each individual plant unit divided by the actual reported annual heat generation (MM Btu) 7) the 2018 Emission Factor was assumed for sources which were thought to be Subject to BART at presumptive levels of 0.15 lb SO2/MM Btu (BART determinations were not finalized in most cases; Utah Hunter & Huntington BART levels were known at 0.12 lb SO2/MM Btu) 8) the 2018 Emission Rate (tons SO2) was calculated by multiplying current year emissions by the ratio of the 2018 to current year Emission Factors 9) the Adjusted 2018 Emission Rate (tons SO2) was "grown" to 85% capacity by multiplying the 2018 Emission Rate by the Growth Ratio from Step 5 (emissions from units already operating at or higher than the 85% capacity in the 2002 data year, were not grown, but accepted at face value)

Non-EGU's

The Methodology for projecting emissions from "Other Industrial Sources" is described in Pechan's October 2006 dated FINAL "2018 SO2 Emissions Evaluation for Non-Utility Sources" Report located on the "Stationary/Area Source Emissions Projections" link from the Stationary Sources Joint Forum Page of the WRAP website: http://www.wrapair.org/forums/ssjf/documents/eictts/projections.html
The SO2 emissions for 19 Natural Gas Processing Plants were updated by Environ in 2007, with additional research into future O&G Operations. The September '07 FINAL Report with the results of of that update is located on the "Oil/Gas Area Source Emissions/Controls" link from the Stationary Source Joint Forum Page of the WRAP website: http://www.wrapair.org/forums/ssjf/documents/eictts/oilgas.html
The 2005 SO2 Milestone Report had some sources which were not picked up in the Pechan report. In those cases, the 2005 emissions were used as a placeholder for the 2018 emission values.
For questions or comments, contact Pat Cummins (pcummins@westgov.org, 970-884-4770) or Lee Gribovicz (lg@westgov.org, 307-778-4927)

## Percentage of Total Existing EGU's # 82,972 58% # Includes 44,801 tons estimated emission reductions due to BART

Non-EGU's # 46,591 33% # Includes 3,370 tons estimated emission reductions due to BART Current Proposed Total 2018 SO2 Actual Emissions 129,563 91%

Permitted/Future New Source Growth * 12,286 9% * Includes 100% of the EGU (6.6K) & Non-Utility (5,686) Growth

Proposed 2018 Milestone 141,849 100% (Annual Tons) 

# 2018 Projected Sulfur Dioxide Emissions

# Existing EGU's 144,619

Non-EGU's 49,961

New Source Set Aside * 6,143 * Includes 50% of the EGU (6.6K) & Non-Utility (5686) Growth

Proposed 2008 Milestone 200,722

Existing EGU's 93,694

Non-EGU's 49,961

New Source Set Aside * 12,286 * Includes 100% of the EGU (6.6K) & Non-Utility (5686) Growth

Proposed 2013 Milestone 155,940 (Annual Tons) 

# 2008 Projected Sulfur Dioxide Emissions

2013 Projected Sulfur Dioxide Emissions (Annual Tons)

# Year Milestones

2008 200,722 2013 155,940 2018 141,849

Calendar Year Year Emissions 1990 467,544 2000 333,163 2018 141,849 0 50,000 100,000 150,000 200,000 250,000



### 2008 2013 2018 SO2 Annual Tons



### Year 

## 309 Milestones

0 100,000 200,000 300,000 400,000 500,000

1990 2000 2018 SO2 Annual Tons



### Year



## Emissions Reduction Progress Achieved Since 1990

### Utility Emissions 2004 SO2 Tons 2005 SO2

Tons 2006 SO2

Tons NM Public Service of NM San Juan 1 2,449 2,823 2,144 3,159 PNM Consent Decree Level NM Public Service of NM San Juan 2 2,980 2,540 2,178 3,142 PNM Consent Decree Level NM Public Service of NM San Juan 3 4,811 5,580 4,463 4,907 PNM Consent Decree Level NM Public Service of NM San Juan 4 5,940 5,627 6,196 4,814 PNM Consent Decree Level NM Raton Public Service Raton Power Plant 1 149 149 estimated 2006 tonnage 149 NM Tri State Generation Prewitt Escalante Station 1 1,228 1,293 970 1,132 UT Intrmntn Power Agency Intermountain 1SGA 1,993 1,773 2,229 2,229 UT Intrmntn Power Agency Intermountain 2SGA 1,856 1,821 2,010 2,010 UT Pacificorp Carbon 1 2,060 2,089 2,787 3,174 UT Pacificorp Carbon 2 3,581 3,321 3,919 4,078 UT Pacificorp Hunter (Emery) 1 2,338 2,548 3,298 3,298 Source assumed @ BART in 2018, but uses 2006 actual tons in 2013 UT Pacificorp Hunter (Emery) 2 2,402 2,485 2,535 2,225 Pacificorp Reductions Operating in 2013 UT Pacificorp Hunter (Emery) 3 987 1,243 1,505 1,581 Pacificorp Reductions Operating in 2013 UT Pacificorp Huntington 1 2,346 2,223 2,889 2,267 Pacificorp Reductions Operating in 2013 UT Pacificorp Huntington 2 14,381 15,139 14,516 1,686 Pacificorp Reductions Operating in 2013 WY Basin Electric Laramie River 1 4,178 4,476 3,190 3,233 WY Basin Electric Laramie River 2 3,833 4,480 3,867 3,915 WY Basin Electric Laramie River 3 4,456 4,143 4,482 4,703 WY Black Hills Power Co Neil Simpson I 1 1,013 1,055 1,055 WY Black Hills Power Co Neil Simpson II 001 532 498 633 estimated 2006 tonnage 633 WY Black Hills Power Co Osage Plant 1 3,094 3,183 3,183 WY Black Hills Power Co Wygen 1 6,618 7,662 6,838 626 WY Pacificorp Dave Johnston BW41 3,071 3,288 3,895 4,035 WY Pacificorp Dave Johnston BW42 3,002 3,395 3,938 3,974 WY Pacificorp Dave Johnston BW43 8,433 7,685 9,061 1,632 Pacificorp Reductions Operating in 2013 WY Pacificorp Dave Johnston BW44 4,310 5,382 5,457 2,827 Pacificorp Reductions Operating in 2013 WY Pacificorp Jim Bridger BW71 6,875 6,701 5,062 3,012 Pacificorp Reductions Operating in 2013 WY Pacificorp Jim Bridger BW72 6,616 5,101 5,734 3,649 Pacificorp Reductions Operating in 2013 WY Pacificorp Jim Bridger BW73 6,039 6,383 5,950 3,430 Pacificorp Reductions Operating in 2013 WY Pacificorp Jim Bridger BW74 3,264 3,466 3,308 3,441 WY Pacificorp Naughton 1 6,618 7,662 6,838 976 Pacificorp Reductions Operating in 2013 WY Pacificorp Naughton 2 8,832 9,464 7,727 1,181 Pacificorp Reductions Operating in 2013 WY Pacificorp Naughton 3 5,723 6,103 6,099 6,099 Source assumed @ BART in 2018, but uses 2006 actual tons in 2013 WY Pacificorp Wyodak BW91 7,862 7,732 6,514 2,240 Pacificorp Reductions Operating in 2013 139,612 148,384 144,619 Utility 93,694 49,961 Non-utility 194,579 Total 2006

111,508 Utility Subject to BART 10,035 Non-utility Subject to BART 62% 121,542 Total Non-CAMD Unit:

Source Emissions from high Milestone Report 

# Existing Electric Generating Units (EGU's) 

# 2018 Projected Sulfur Dioxide Emissions

2013 SO2 Emissions* STATE Company Plant Name ID Recent Emission RatesEGU Data & Calculations

STATE PLNAME ID Design Capacity MW 2002

Production MWh 2003

Production MWh 2004

Production MWh 2005

Production MWh 2002 CF 2003 CF 2004 CF 2005 CF Growth Factor 2002- 18 Growth Factor 2003- 18 Growth Factor 2004- 18 Growth Factor 2005- 18 Average

Growth Factor 2006 HI

(Mbtu) 2006 SO2

Tons 2006 SO2

(#/mmbtu) 2018 SO2

(#/mmbtu) 2018 Emissions @

'06 factors Growth Factor

to 85% Capacity Resultant 2018

Emissions 2018 Baseline (#/mmbtu) 2018 Baseline

Emissions NM Public Service of NM San Juan 1 369 2.50E+06 2.48E+06 2.38E+06 2.57E+06 0.77 0.77 0.74 0.79 1.10 1.11 1.15 1.07 1.11 2.5E+07 2,144 0.17 0.150 1,855 1.11 2,056 201 0.159 2,179 NM Public Service of NM San Juan 2 369 2.75E+06 2.04E+06 2.46E+06 2.33E+06 0.85 0.63 0.76 0.72 1.00 1.34 1.12 1.18 1.16 2.6E+07 2,178 0.17 0.150 1,960 1.16 2,274 314 0.159 2,410 NM Public Service of NM San Juan 3 555 4.11E+06 3.44E+06 3.53E+06 3.72E+06 0.85 0.71 0.73 0.77 1.01 1.20 1.17 1.11 1.12 3.7E+07 4,463 0.24 0.150 2,767 1.12 3,103 336 0.159 3,289 NM Public Service of NM San Juan 4 555 4.24E+06 3.37E+06 4.16E+06 3.85E+06 0.87 0.69 0.85 0.79 1.00 1.23 0.99 1.07 1.07 3.9E+07 6,196 0.31 0.150 2,958 1.07 3,176 218 0.159 3,367 NM Tri State Generation Prewitt Escalante Station 1 257 1.21E+06 1.86E+06 1.80E+06 1.91E+06 0.54 0.83 0.80 0.85 1.58 1.03 1.06 1.00 1.17 1.5E+07 970 0.13 0.13 970 1.17 1,132 163 0.13 1,132 UT Intrmntn Power Agency Intermountain 1SGA 820 7.24E+06 6.63E+06 7.63E+06 6.49E+06 1.01 0.92 1.06 0.90 1.00 1.00 1.00 1.00 1.00 8.3E+07 2,229 0.05 0.05 2,229 1.00 2,229 0 0.05 2,229 UT Intrmntn Power Agency Intermountain 2SGA 820 6.96E+06 6.92E+06 6.80E+06 7.18E+06 0.97 0.96 0.95 1.00 1.00 1.00 1.00 1.00 1.00 7.3E+07 2,010 0.05 0.05 2,010 1.00 2,010 0 0.05 2,010 UT Pacificorp Carbon 1 75 5.75E+05 5.20E+05 3.93E+05 5.26E+05 0.87 0.79 0.60 0.80 1.00 1.07 1.42 1.06 1.14 6.5E+06 2,787 0.85 0.85 2,787 1.14 3,174 387 0.85 3,174 UT Pacificorp Carbon 2 114 8.48E+05 8.51E+05 7.42E+05 8.23E+05 0.85 0.85 0.75 0.83 1.00 0.99 1.14 1.03 1.04 9.3E+06 3,919 0.84 0.84 3,919 1.04 4,078 159 0.84 4,078 UT Pacificorp Hunter (Emery) 1 488 3.48E+06 3.35E+06 3.05E+06 3.09E+06 0.81 0.78 0.71 0.72 1.05 1.09 1.19 1.18 1.13 3.8E+07 3,298 0.18 0.12 2,258 1.13 2,541 283 0.18 3,712 UT Pacificorp Hunter (Emery) 2 488 2.94E+06 3.12E+06 3.34E+06 3.27E+06 0.69 0.73 0.78 0.77 1.24 1.17 1.09 1.11 1.15 3.2E+07 2,535 0.16 0.12 1,935 1.15 2,225 290 0.16 2,915 UT Pacificorp Hunter (Emery) 3 496 3.63E+06 3.48E+06 3.58E+06 3.38E+06 0.84 0.80 0.82 0.78 1.02 1.06 1.03 1.09 1.05 3.4E+07 1,505 0.09 0.09 1,505 1.05 1,581 75 0.09 1,581 UT Pacificorp Huntington 1 498 3.49E+06 3.47E+06 3.00E+06 3.07E+06 0.80 0.79 0.69 0.70 1.06 1.07 1.24 1.21 1.14 3.3E+07 2,889 0.17 0.12 1,981 1.14 2,267 286 0.17 3,306 UT Pacificorp Huntington 2 446 2.86E+06 3.75E+06 3.39E+06 3.31E+06 0.73 0.96 0.87 0.85 1.16 1.00 1.00 1.00 1.04 2.7E+07 14,516 1.09 0.12 1,619 1.04 1,686 67 0.12 1,672 WY Basin Electric Laramie River 1 570 4.63E+06 4.03E+06 4.40E+06 4.45E+06 0.93 0.81 0.88 0.89 1.00 1.05 1.00 1.00 1.01 4.4E+07 3,190 0.15 0.15 3,190 1.01 3,233 43 0.15 3,233 WY Basin Electric Laramie River 2 570 4.76E+06 4.53E+06 4.04E+06 4.72E+06 0.95 0.91 0.81 0.95 1.00 1.00 1.05 1.00 1.01 5.3E+07 3,867 0.15 0.15 3,867 1.01 3,915 48 0.15 3,915 WY Basin Electric Laramie River 3 570 3.87E+06 4.54E+06 4.39E+06 3.85E+06 0.78 0.91 0.88 0.77 1.10 1.00 1.00 1.10 1.05 5.2E+07 4,482 0.17 0.15 3,878 1.05 4,070 192 0.15 4,070 WY Black Hills Power Co Neil Simpson II 2 80 6.86E+05 6.49E+05 n/a n/a 0.98 0.93 n/a n/a 1.00 1.00 1.00 9.2E+06 633 0.14 0.14 633 1.00 633 0 0.14 633 WY Black Hills Power Co Wygen 1 80 7.41E+05 7.09E+05 n/a n/a 1.06 1.01 n/a n/a 1.00 1.00 1.00 9.8E+06 626 0.13 0.13 626 1.00 626 0 0.13 626 WY Pacificorp Dave Johnston BW41 114 8.87E+05 7.51E+05 8.33E+05 8.58E+05 0.89 0.75 0.84 0.86 1.00 1.13 1.02 1.00 1.04 1.0E+07 3,895 0.75 0.75 3,895 1.04 4,035 140 0.75 4,035 WY Pacificorp Dave Johnston BW42 114 9.18E+05 8.39E+05 8.22E+05 8.47E+05 0.92 0.84 0.83 0.85 1.00 1.01 1.03 1.00 1.01 1.0E+07 3,938 0.75 0.75 3,938 1.01 3,974 36 0.75 3,974 WY Pacificorp Dave Johnston BW43 230 1.87E+06 1.65E+06 1.62E+06 1.54E+06 0.93 0.82 0.81 0.77 1.00 1.04 1.05 1.11 1.05 2.1E+07 9,061 0.87 0.15 1,554 1.05 1,632 77 0.87 9,512 WY Pacificorp Dave Johnston BW44 360 2.60E+06 2.07E+06 2.55E+06 2.44E+06 0.82 0.65 0.81 0.77 1.03 1.30 1.05 1.10 1.12 3.4E+07 5,457 0.32 0.15 2,522 1.12 2,827 304 0.32 6,115 WY Pacificorp Jim Bridger BW71 578 3.59E+06 3.83E+06 4.02E+06 3.87E+06 0.71 0.76 0.79 0.76 1.20 1.12 1.07 1.11 1.13 3.6E+07 5,062 0.28 0.15 2,675 1.13 3,012 336 0.28 5,699 WY Pacificorp Jim Bridger BW72 578 3.97E+06 3.88E+06 3.71E+06 3.27E+06 0.78 0.77 0.73 0.65 1.08 1.11 1.16 1.32 1.17 4.2E+07 5,734 0.28 0.15 3,126 1.17 3,649 522 0.28 6,692 WY Pacificorp Jim Bridger BW73 578 4.21E+06 3.10E+06 3.65E+06 3.90E+06 0.83 0.61 0.72 0.77 1.02 1.39 1.18 1.10 1.17 3.9E+07 5,950 0.31 0.15 2,925 1.17 3,430 505 0.31 6,977 WY Pacificorp Jim Bridger BW74 584 3.80E+06 3.67E+06 3.38E+06 3.75E+06 0.74 0.72 0.66 0.73 1.14 1.18 1.29 1.16 1.19 3.8E+07 3,308 0.17 0.15 2,884 1.19 3,441 557 0.15 3,441 WY Pacificorp Naughton 1 163 1.19E+06 1.27E+06 1.15E+06 1.25E+06 0.83 0.89 0.81 0.87 1.02 1.00 1.05 1.00 1.02 1.3E+07 6,838 1.07 0.15 959 1.02 976 17 1.07 6,960 WY Pacificorp Naughton 2 218 1.53E+06 1.47E+06 1.53E+06 1.60E+06 0.81 0.77 0.80 0.84 1.06 1.11 1.06 1.01 1.06 1.5E+07 7,727 1.04 0.15 1,116 1.06 1,181 65 1.04 8,173 WY Pacificorp Naughton 3 326 2.66E+06 2.06E+06 2.56E+06 2.38E+06 0.93 0.72 0.90 0.83 1.00 1.18 1.00 1.02 1.05 2.9E+07 6,099 0.41 0.15 2,212 1.05 2,321 109 0.41 6,399 WY Pacificorp Wyodak BW91 362 3.20E+06 2.75E+06 2.69E+06 2.68E+06 1.01 0.87 0.85 0.84 1.00 1.00 1.00 1.01 1.00 2.8E+07 6,514 0.47 0.15 2,100 1.00 2,100 0 0.47 6,514 Units w/o 2006 EIA Data Raton Power Plant 149 149

-> BH Neil Simpson I 1,055 1,055

-> BH Osage 3,183 3183

-> 82,972 5,730 128,409

EGU Emission Reduction due to BART 45,437

Non-EGU Estimated Emission Reduction due to BART 3300

Total Emission Reduction due to BART 48,737 Unit Operating above 85% Capacity

Page 6

### SIC Primary Code NAICS Primary Code Industry Sector

WY Basin Electric Dry Fork 1 4911 221112 

### Fossil Fuel Electric Generation 1,332 4,124 WY Black Hills Power Co Wygen 2 4911 221112 

### Fossil Fuel Electric Generation 569 WY Black Hills Power Co Wygen 3 4911 221112 

### Fossil Fuel Electric Generation 512 WY Two Elk Partners Two Elk #1 4911 221112 

### Fossil Fuel Electric Generation 1,711

Projected New Plant Future Coal EGU A 1 4911 221112 

### Fossil Fuel Electric Generation 1,250 Projected New Plant Future Coal EGU B 1 4911 221112 

### Fossil Fuel Electric Generation 1,250 EGU Totals 6,624

New source growth per year between 2006 and 2018 0.4% 

## Utility Emissions 2018 SO2 Emissions 

# 2018 Projected Sulfur Dioxide Emissions

Emission Sector

STATE Company Plant Name ID



# Future Electric Generating Units (EGU's)SIC Primary Code NAICS Primary Code Industry Sector

2005 Milestone Report Values 2006

Milestone Draft Values NM Agave Energy (Yates) Dagger Draw Gas Plant 1311 211111 Oil/Gas 263 1,936 263 NM Duke Energy Artesia Gas Plant 1321 211112 Oil/Gas 19 528 162 NM Duke Energy Burton Flats 1321 211112 Oil/Gas 1 1 0 NM Duke Energy Dagger Draw Gas Plant 1321 211112 Oil/Gas 243 0 0 NM Duke Energy Eunice Gas Plant 1321 211112 Oil/Gas 1,801 305 1,178 NM Duke Energy Linam Ranch Gas Plant 1321 211112 Oil/Gas 26 1,874 1,558 NM Frontier Empire Abo Plant 1321 211112 Oil/Gas 630 295 307 NM Frontier Maljamar Gas Plant 1321 211112 Oil/Gas 3,574 2,163 2,430 NM Giant Refining Ciniza Plant 2911 32411 Refining 996 942 840 NM Giant Refining San Juan Refinery (Bloomfield) 2911 32411 Refining 476 393 385 NM JL Davis Denton Plant 1311 211111 Oil/Gas 295 771 1,125 NM Marathon Indian Basin Gas Plant 1311 211111 Oil/Gas 1,100 905 809 NM Navajo Refining Artesia 2911 32411 Refining 1,171 102 160 NM Sid Richardson Jal No. 3 1321 211112 Oil/Gas 1,231 1,401 1,435 NM Targa (Dynenergy) Eunice Gas Plant 1321 211112 Oil/Gas 55 2,567 2,041 NM Targa (Dynenergy) Eunice South Gas Plant 1321 211112 Oil/Gas 25 1 0 NM Targa (Dynenergy) Monument Plant 1321 211112 Oil/Gas 1,432 1,114 1,179 NM Targa (Dynenergy) Saunders Plant 1321 211112 Oil/Gas 28 358 545 NM Western Gas Resources San Juan River Gas Plant 1321 211112 Oil/Gas 735 392 461 UT BYU Main Campus 8221 611310 Misc. 97 154 154 UT Brush Resources Delta Mill 1099 212299 0 0 0 UT Chevron Salt Lake Refinery 2911 324110 Refining 1,268 2,201 1,174 UT EnCana O&G Lisbon Plant 1311 211111 Oil/Gas 2,119 293 118 UT Flying J Refinery (Big West Oil Co.) 2911 324110 Refining 261 361 341 UT Graymont Western US Cricket Mountain Plant 3274 212312 Lime 461 8 34 UT Holcim Devil's Slide Plant 3241 327310 Cement 83 229 451 UT Kennecott Power Plt/ Lab/ Tailings 1021 212234 Copper 1,916 3,009 2,955 UT Kennecott Smelter & Refinery 3331 331411 Copper 1,000 777 737 UT Phillips Woods Cross Refinery 2911 324110 Refining 567 574 478 UT Sunnyside Cogeneration Facility 4911 221112 Cogeneration 704 932 858 UT Tesoro Salt Lake City Refinery 2911 324110 Refining 718 880 940 UT Utelite Shale Processing 3295 212399 Metals/Mining 121 167 174 WY American Colloid East Colony Bentonite 1459 212325 Bentonite 211 211 73 WY American Colloid West Colony Bentonite 1459 212325 Bentonite 180 180 53 WY Anadarko (aka UPRC) Brady Gas Plant 1321 211112 Oil/Gas 181 84 89 WY Anadarko (aka UPRC) Table Rock Gas Plant 1321 211112 Oil/Gas 250 250 145 WY Big Horn Gas Processing Byron Gas Plant 1321 211112 Oil/Gas 0 0 0 WY BP America Whitney Canyon Gas Plant 1311 211111 Oil/Gas 0 3,590 2,257 WY BP America Whitney Canyon Wellfield 1311 Oil/Gas 2 2 0 WY Burlington Resources Bighorn Wells 1311 Oil/Gas 3,154 0 0 WY Burlington Resources Lost Cabin Gas Plant 1311 211111 Oil/Gas 2,378 1,232 1,715 WY Chevron USA Carter Creek Gas Plant 1311 211111 Oil/Gas 284 1,122 205 WY Chevron USA Table Rock Well Field 1311 Oil/Gas 219 0 269 WY Chevron USA Whitney Canyon/Carter Creek Wellfield 1311 Oil/Gas 1,184 385 219 WY Devon Energy Beaver Creek Gas Plant 1311 211111 Oil/Gas 42 106 160 WY Exxon Black Canyon Dehy Well Flaring 1311 Oil/Gas 119 20 119 WY Exxon Shute Creek Sour Gas Plant 1311 211111 Oil/Gas 1,260 2,300 2,205 WY FMC Corp Granger Soda Ash Plant 2812 327999 Nonmetallic Minerals 270 54 161 WY FMC Corp Green River Soda Ash Plant 2812 327999 Nonmetallic Minerals 3,497 5,005 4,579 2018 Emission Projection Determined by the State (includes an estimated 700 ton emission reductions achievable due to BART) WY Frontier Refining, Inc. Cheyenne Refinery 2911 324110 Refining 1,292 1,438 973 WY General Chemical Green River Soda Ash Plant 1474 327999 Nonmetallic Minerals 2,787 5,216 5,456 2018 Emission Projection Determined by the State (includes an estimated 2600 ton emission reductions achievable due to BART) WY Hiland Partners Hiland Gas Plant 1321 48621 Oil/Gas 385 109 141 WY Encore Energy (aka Howell) Elk Basin Gas Plant 1311 211111 Oil/Gas 1,500 1,313 1,429 WY Marathon Oil Co Oregon Basin Gas Plant 1321 211112 Oil/Gas 350 328 447 WY Mountain Cement Co Laramie Plant 3241 23571 Cement 314 139 92 WY P4 Production Rock Springs Coking Plant 3312 331111 Comm. Fuel Combust 1,008 618 706 WY Simplot Phosphates, Inc Rock Springs Fertilizer Plant 2874 325312 Chemicals 2,015 2,003 2,219 WY Sinclair Oil Corp Casper Refinery 2911 324110 Refining 1,165 742 691 WY Sinclair Oil Corp Sinclair Refinery 2911 324110 Refining 3,709 1,740 1,260 WY Solvay Minerals Green River Soda Ash Plant 1474 327999 Nonmetallic Minerals 68 68 64 WY Western Sugar Torrington Plant 2063 311313 Comm. Fuel Combust 143 131 143 WY Univ Of Wyoming Central Heat Plant 8221 221112 Misc. 189 150 69 WY Wyoming Refining Co Newcastle Refinery 2911 324110 Refining 705 762 732 Non-EGU Totals 52,277 54,931 49,961

Non-Utility New Source Growth = Difference between Current (2006) Emissions and 2018 Projections 5,686 Excluding BART emission reductions 0.9% Growth per year between 2006 and 2018 * (for non-EGU's: 2018 Emissions as in October '06 Pechan Report )

Source reported in 2005 Milestone Report, but not addressed by Pechan Projections (highest recent emission value used) Non-Utility Sources which are "Subject to

BART" 

# 2018 Projected Sulfur Dioxide Emissions

Emission Sector

STATE Company Plant Name ID 

# Other Industrial Sources (Non-EGU's) Updates to Pechan report from the April '07 Environ Gas Plant review

2018 Emission Projection Determined by the State 

### Non-Utility Emissions 2018 Emission Projection Determined by the State 2018 SO2 Emissions* Recent Emission Rates

# 1990 2000 2002 (Plan02d) 2006

Milestone Report 2008

Milestone 2013

Milestone 2018

(PRP18b) 2018

Milestone

NM 140,177 79,011 37,918 31,068 31,012 UT 84,983 37,483 42,183 44,175 35,429 WY 133,204 122,373 120,991 113,465 96,809 3

- State Total 358,364 238,867 201,092 188,708 200,722 155,940 163,250 141,849 - 50,000 100,000 150,000 200,000 250,000 300,000 350,000 400,000 Tons per year 

# § 309 SO 2 

# Backstop Cap and Trade Program

- Emissions, Modeling EI, and Milestone Program Data (no tribal sources)

# 309 State Trends

1990 2000 2002 (Plan02d) 2006

Milestone Report 2008

Milestone 2013

Milestone 2018

(PRP18b) 2018

Milestone NM 140,177 79,011 37,918 31,068 31,012 UT 84,983 37,483 42,183 44,175 35,429 WY 133,204 122,373 120,991 113,465 96,809 3-State Total 358,364 238,867 201,092 188,708 200,722 155,940 163,250 141,849

33% 60%

# Milestone Tribal Set-aside New

Source Set-Aside Remaining

Allocation Utility

Portion Non-utility

Portion 2008 269,083 2,500 6,143 260,440 210,480 49,961 2009 234,903 2,500 6,143 226,260 176,299 49,961 2010 200,722 2,500 6,143 192,079 142,119 49,961 2011 200,722 2,500 6,143 192,079 142,119 49,961 2012 200,722 2,500 6,143 192,079 142,119 49,961 2013 185,795 2,500 12,286 171,009 121,048 49,961 2014 170,868 2,500 12,286 156,082 106,121 49,961 2015 155,940 2,500 12,286 141,154 91,194 49,961 2016 155,940 2,500 12,286 141,154 91,194 49,961 2017 155,940 2,500 12,286 141,154 91,194 49,961 2018 141,849 2,500 12,286 127,063 80,402 46,661