List of Worksheets

Emissions - This lists some historical and projected (WY proposed limits) emissions data

Plant Data Summary - This is key input data and assumptions for the cost estimating worksheets

NOx-LNB_20yr This has the calculations for combustion controls based upon a post combustion control emissions and 20 yr life

NOx-LNB<20yr This has the calculations for combustion controls based upon a post combustion control emissions and under 20 yr life

NOx-SNCR_20 This has the calculations for SNCR based upon a post combustion control emissions and 20 year life

NOx-SNCR<20 This has the calculations for SNCR based upon a post combustion control emissions and under 20 year life

NOx-SCR_20 This has the calculations for SCR based upon a post combustion control emissions and 20 year life

NOx-SCR<20 This has the calculations for SCR based upon a post combustion control emissions and under 20 year life

SCR Cost Comparison This compares estimated SCR capital cost from different sources

Dave Johnston_20_IPM This summarizes cost and emissions calculations for units at Dave Johnston plant using IPM for all SCR costs

Dave Johnston_20 This summarizes cost and emissions calculations for units at Dave Johnston plant

Dave Johnston<20 This summarizes cost and emissions calculations for Dave Johnston plant with early retirement

Laramie River_IPM This summarizes cost and emissions calculations for units at Laramie River plant using IPM for all SCR costs

Laramie River This summarizes cost and emissions calculations for units at Laramie River plant

Naughton_20_IPM This summarizes cost and emissions calculations for units at Naughton plant using IPM for all SCR costs

Naughton_20 This summarizes cost and emissions calculations for units at Naughton plant

Naughton<20 This summarizes cost and emissions calculations for Naughton 1 and 2 with early retirement

Wyodak This summarizes cost and emissions calculations for units at Wyodak plant

CEPCI This shows historical Chemical Engineering Plant Cost Index (CEPCI) data

TVA_SCR Cost This is a table of SCR costs for TVA
d under 20 yr life
 Facility Name Facility ID (ORISPL) Unit ID

2001 2001 2003 Avg 2001 2001 2003 Avg 2001 2001 2003 Avg Capacity (MW) Heat Rate (Btu/kW-h) Avg Capacity Factor 2003 NOx Control(s) Boiler type

WY Proposed BART limit or 

comb. Controls only 

estimate

2011NOx 2012 NOx 2013 

Q1&Q2

Dave Johnston 4158 BW41 2259.654 2341.398 1993.66 2198.237 0.4387 0.4737 0.4523 0.4549 10271469 9859291 8724168 9618309 106 11121 93.1% Dry bottom wall-fired boiler 0.2 0.3864 0.4080 0.3844

Dave Johnston 4158 BW42 2025.349 2298.038 2191.427 2171.605 0.4292 0.455 0.4376 0.4406 9389438 10052222 9988892 9810184 106 11112 95.1% Dry bottom wall-fired boiler 0.2 0.4273 0.4235 0.4146

Dave Johnston 4158 BW43 4834.257 5027.037 5057.173 4972.822 0.521 0.5013 0.5124 0.5116 18276800 19819756 19531122 19209226 220 11098 89.8% Cell burner boiler 0.28 0.2261 0.2113 0.2273

Dave Johnston 4158 BW44 4788.221 5352.534 5270.734 5137.163 0.3374 0.3638 0.3974 0.3662 27903324 29081693 26078697 27687905 330 10964 87.4% Tangentially-fired 0.15 0.1413 0.1543 0.1323

Laramie River 6204 1 6040.086 6728.234 5613.917 6127.412 0.2474 0.2769 0.2512 0.2585 48243920 48061877 44137502 46814433 565 11312 83.6% Low NOx Burner Technology (Dry Bottom only) Dry bottom wall-fired boiler 0.21 0.1843 0.1718 0.1660

Laramie River 6204 2 5631.559 6686.953 6726.763 6348.425 0.2717 0.2729 0.2664 0.2703 40954490 48607656 50111065 46557737 570 10953 85.1% Low NOx Burner Technology (Dry Bottom only) Dry bottom wall-fired boiler 0.21 0.1838 0.1893 0.2097

Laramie River 6204 3 6323.325 5544.715 7369.091 6412.377 0.2463 0.272 0.2825 0.2669 50975075 40466512 51855000 47765529 570 11686 81.9% Low NOx Burner Technology (Dry Bottom only) Dry bottom wall-fired boiler 0.21 0.2174 0.1945 0.2073

Naughton 4162 1 3694.826 3365.114 3721.047 3593.662 0.5122 0.5216 0.5126 0.5155 14372707 12583677 14405088 13787157 160 10848 90.7% Tangentially-fired 0.26 0.5892 0.3389 0.2176

Naughton 4162 2 4554.524 4306.428 4432.165 4431.039 0.5061 0.5266 0.5335 0.5221 17799227 15835524 16214540 16616431 210 10708 84.4% Tangentially-fired 0.26 0.5641 0.2157 0.2305

Naughton 4162 3 4594.486 5240.761 4033.023 4622.757 0.3608 0.3685 0.3675 0.3656 24989045 28425577 21154475 24856366 330 10489 82.0% Tangentially-fired 0.07 0.4333 0.3454 0.2861

Wyodak 6101 BW91 4600.661 4696.526 4662.886 4653.358 0.2537 0.2618 0.271 0.2622 35964854 35685721 33961751 35204108 335 12068 99.4% Dry bottom wall-fired boiler 0.23 0.2062 0.1906 0.1937

Notes: 1 1 1 1 1 1 1 1 1 1 1 1 2 2 3 1 1 4 1 1 1

1 Data is from Air Markets Program Data; 2012 YTD is total tons NOx times 2000 divided by heat input. For LR1, months of Apr and May are excluded due to shutdown in Apr and apparent use of natural gas or other (zero SO2 emissions) in May

2 From NEEDS v 4.10

3 Calculated from avg heat input for 2001-2003, capacity and heat rate

4 From FR vol 77, No 107, except Laramie River which were subsequently reduced to 0.21

NOx Emissions (tpy) NOx Emissions (lb/MMBtu) Heat Input (MMBtu) NEEDS Data
1 2 3 4 5 6 8 9 10 11 13 14 15 16 17 18 19 20 21 23 24 25 26 27

Capacity baseline rate 2001-2003

Unique ID Name

Plant 

Code

Unit MW gross Fuel

WY Proposed BART 

limit or comb. 

Controls only 

estimate

2011NOx 2012 YTD 2001-2003 Estim. Capac. 

Factor

Heat Rate Burner

2003 

Controls

Add'l 

Controls

2011 

Controls

Add'l 

Controls

Final NOx with 

Comb Controls

% red'n from 2003 

emissions with comb 

controls

SCR Retrofit Factor

Altitude, feet

Alternative lifetime 

(SNCR and SCR) Power Cost, $/kWh SNCR utilization

4158_BW41 Dave Johnston 4158.00 BW41 106 C 0.20 0.3864 0.3934 0.45 0.9314 11121 W LNBO LNBO 0.2000 56.0% 1.50 4,950 20 0.0201 25.0% Dry bottom wall-fired boiler

4158_BW42 Dave Johnston 4158.00 BW42 106 C 0.20 0.4273 0.4328 0.44 0.9508 11112 W LNBO LNBO 0.2000 54.6% 1.50 4,950 20 0.0201 25.0% Dry bottom wall-fired boiler

4158_BW43 Dave Johnston 4158.00 BW43 220 C 0.28 0.2261 0.2162 0.51 0.8981 11098 W LNBO LNBO 0.2162 57.7% 1.50 4,950 9 0.0201 25.0% Cell burner boiler

4158_BW44 Dave Johnston 4158.00 BW44 330 C 0.15 0.1413 0.2039 0.37 0.8736 10964 T LNC3 LNC3 0.1413 61.4% 1.50 4,950 20 0.0201 25.0% Tangentially-fired

6204_1 Laramie River 6204.00 1.00 565 C 0.21 0.1843 0.1930 0.26 0.8362 11312 W LNB OFA LNBO 0.1920 25.7% 1.00 4,750 20 0.0150 12.0% Dry bottom wall-fired boiler

6204_2 Laramie River 6204.00 2.00 570 C 0.21 0.1838 0.1901 0.27 0.8513 10953 W LNB OFA LNBO 0.1920 29.0% 1.20 4,750 20 0.0150 12.0% Dry bottom wall-fired boiler

6204_3 Laramie River 6204.00 3.00 570 C 0.21 0.2174 0.1930 0.27 0.8186 11686 W LNB OFA LNBO 0.1920 28.1% 1.00 4,750 20 0.0150 12.0% Dry bottom wall-fired boiler

4162_1 Naughton 4162.00 1.00 160 C 0.26 0.5892 0.5551 0.52 0.9068 10848 T LNC3 LNC3 0.2108 59.1% 1.30 6,939 11 0.0227 25.0% Tangentially-fired

4162_2 Naughton 4162.00 2.00 210 C 0.26 0.5641 0.2108 0.52 0.8436 10708 T LNC3 LNC3 0.2108 59.6% 1.30 6,939 11 0.0227 25.0% Tangentially-fired

4162_3 Naughton 4162.00 3.00 330 C 0.07 0.4333 0.3984 0.37 0.8197 10489 T LNC2 LNC2 0.3300 9.7% 1.30 6,939 20 0.0227 25.0% Tangentially-fired

6101_BW91 Wyodak 6101.00 BW91 335 C 0.23 0.2062 0.1918 0.26 0.9940 12068 W LNBO LNBO 0.1918 26.8% 1.30 4,420 20 0.0160 25.0% Dry bottom wall-fired boiler

Notes: 1 2 2 3 4 5 2 2 2 2 6 7 8 9 10

Notes 1

2

3

4

5

6

7

8 Site elevations from 2008 BART submittals or company comments

9 Dave Johnston 3, Naughton 1 and 2 alternative lifetimes based upon comments from Pactiforp page 37

10 Power cost for Pacificorp units from FERC Form 1, Annual Report of Major Electric Utilities, Licensees and Others and Supplemental Form 3Q: Quarterly Financial Report, Year/Period 2010/Q4

Power cost for Laramie River Station: Basin Electric Power Cooperative Laramie River Station Refined BART Visibility Modeling, July 2008, pdf pg 25 of 176

Economic Assumptions: 

Capital Recovery Factor 9.44% Combustion control legend

Interest Rate 7.00% LNB Low NOx Burner

Period (yrs) 20 LNBO Low NOx Burner and Overfire Air

OFA Overfire Air

Insurance 0.30% From Integrated Planning Model ver 4.10 documentationpage 8-11 LNC3 For tangential units, LNB with separated OFA

Property Taxes 0.90% From Integrated Planning Model ver 4.10 documentationpage 8-11

Cost of Urea (50% wt soln) 450 $/ton 10/12/12 email from Doug Kirk, Fuel Tech

Cost of anh. NH3 625 $/ton email from Jennifer Zagorsky, Potash Corp. 9/27/13

Cost of Oper Labor 60 $/hr Cichanowicz, 2010

Cost of SCR catalyst 5500 $/m3 Cichanowicz, 2010

Cost of steam 4.00 $/1000lb IPM model assumptions

cost of dilution water 1.00 $/1000gal IPM model assumptions

These are subjective factors that account for a presumed retrofit difficulty. The rationale for the selection of each of these factors is described in the memo submitted with this workbook

2011 Reported Rates

Rate with combustion controls. This is the lesser of 2011 annual rate, 2012 YTD, or rate committed to or published in FR 77 No. 107 For DJ 1 and 2, this results in 0.20 lb/MMBtu. For Naughton 1 assumed the same rate as Naughton 2 and for Naughton 3, I assumed 10% under the WY proposed 30 day average rate with comb controls, or 10% under 0.37, which is equal to 0.33. For LR 1, 2, 3, used 

the average of the 2012 YTD values.

This is the lesser of the WY BART limit or the combustion controls only estimate in the BART analyses. The 0.20 limit for DJ 1 and 2 is taken from the proposal in the FR, and is a reasonable estimate for LNBO at about 55% NOx reduction from the 2003 rate.

Determined from data reported to US EPA and available on the Clean Air Markets Division Web Site; 2012 YTD is total tons NOx times 2000 divided by heat input. For LR1, months of Apr and May are excluded due to shutdown in Apr and apparent use of natural gas in May

Baseline rate for 2003 is average for 2001-2003 reported rates.

Capacity factor estimated for 2001-2003 from reported heat input, NEEDS heat rate and NEEDS capacity in MW. Used to calculate annual NOx emissions from average annual rate

Heat rate from NEEDS v4.10
BASE COSTS

Control Scenario Boiler Type TECHNOLOGY Capital FOM VOM REM Eff SCALING FACTORS (TPC and FOM)

($/kw) ($/kw-yr) mills/kwhr)

1.00 Wall-Fired LNB 45.00 0.30 0.07 0.30 Wall- and T-fired = (base cost)*(300/MW)^0.359 See Chapter 5

2.00 Wall-Fired LNBO 61.00 0.40 0.09 0.50 http://www.epa.gov/airmarkets/progsregs/epa-ipm/BaseCasev410.html#documentation

3.00 Wall-Fired OFA 24.00 0.40 0.09 0.29 It is assumed that OFA installed alone costs 1.5 times the difference between LNB+OFA and LNB alone

4.00 T-Fired LNC1 24.00 0.20 0.00 0.30 Vertical-fired = (base cost)*(300/MW)^0.553

5.00 T-Fired LNC2 33.00 0.20 0.03 0.50

6.00 T-Fired LNC3 38.00 0.30 0.03 0.60

7.00 T-Fired LNC1_3 21.00 0.10 0.03 0.20 use upgrade to LNFC 3 - Capital=(LNC3-LNC1)*1.5; FOM/VOM = LNC3-LNC1; Nox=20%

0.00 0.00 0.00 0.00 0.00

Note: percent reduction in this table was not used because actual or projected emissions data was available for each unit

Variable Designation Units Value Calculation

Unique ID 4158_BW41 4158_BW42 4158_BW43 4158_BW44 6204_1 6204_2 6204_3 4162_1 4162_2 4162_3 6101_BW91 1

Plant Dave Johnston Dave Johnston Dave Johnston Dave Johnston Laramie River Laramie River Laramie River Naughton Naughton Naughton Wyodak 2

Unit BW41 BW42 BW43 BW44 1 2 3 1 2 3 BW91 3

Unit Size A MW 106 106 220 330 565 570 570 160 210 330 335 user input 4

Gross Heat Rate C Btu/kwhr 11120.94 11111.77 11097.8 10963.53 11312 10953 11686 10848.17 10707.82 10489.42 12068.4 user input 5

NOx Rate D lb/Mmbtu 0.4549 0.4406 0.511566667 0.3662 0.2585 0.270333333 0.266933333 0.515466667 0.522066667 0.3656 0.262166667 user input 6

CF J % 93.14% 95.08% 89.81% 87.36% 83.62% 85.13% 81.86% 90.68% 84.36% 81.97% 99.40% user input 7

NOx Controls LNBO LNBO LNBO LNC3 OFA OFA LNBO LNC3 LNC3 LNC2 LNBO 8

Retrofit Factor B 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1 = typical retrofit 9

Heat Input I Btu/hr 1.18E+09 1.18E+09 2.44E+09 3.62E+09 6.39E+09 6.24E+09 6.66E+09 1.74E+09 2.25E+09 3.46E+09 4.04E+09 A*C*1000 10

11

NOx Removal Eff K % 56.03% 54.61% 57.73% 61.41% 25.72% 28.97% 28.07% 59.10% 59.61% 9.74% 26.84% from Plant Data Sheet 12

NOx Removed M lb/hr 300.48 283.39 721.08 813.68 424.92 488.95 499.03 528.75 699.84 123.23 284.53 D*I/10^6*K 13

Aux Power Cost T $/kwh 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 14

Steam Cost U $/Klb 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 15

Operating Labor Rate V $/hr 60.00 60.00 60.00 60.00 60.00 60.00 60.00 60.00 60.00 60.00 60.00 Total Labor Cost 16

17

18

19

March 2008 reported cost, including AFUDC and Owner's cost 17500000 7900000 9,600,000 9,100,000 13,100,000 From March 2008 Addendum 20

TPC ($) (excluding AFUDC and Owners cost) = 10,099,943 12,219,701 15,976,696 7,212,337 21,118,000 21,118,000 21,118,000 8,764,359 8,307,882 1,000,000 11,959,698 Total project cost 21

Base Cost (from IPM algorithm) 61 61 61 38 24 24 61 38 38 33 61 22

23

TPC ($/kw) = 95.3 115.3 72.6 21.9 37.4 37.0 37.0 54.8 39.6 3.0 35.7 24

Fixed O&M Cost 25

26

FOM ($/kw-yr) = 0.58 0.58 22000.00 22000.00 22000.00 Total Fixed O&M Cost LR Fixed O&M from July 2008 Black & Veatch, DJ 3&4, N & W from WY SIP Attachments, else IPM 27

28

VOM ($/MWhr) = 0.09 0.09 Total Variable O&M Cost LR var O&M from July 2008 Black & Veatch, DJ 3&4, N & W from WY SIP Attachments, else IPM 29

30

CR = 9.44% 9.44% 9.44% 9.44% 9.44% 9.44% 9.44% 9.44% 9.44% 9.44% 9.44% 31

Property Taxes and Insurance 1.20% 1.20% 1.20% 1.20% 1.20% 1.20% 1.20% 1.20% 1.20% 1.20% 1.20% 32

Total Charge Rate 10.64% 10.64% 10.64% 10.64% 10.64% 10.64% 10.64% 10.64% 10.64% 10.64% 10.64% 33

34

35

Cost of control - $/Ton 36

CF 93% 95% 90% 87% 84% 85% 82% 91% 84% 82% 99% 37

Control Efficiency 56% 55% 58% 61% 26% 29% 28% 59% 60% 10% 27% 38

Uncontrolled Rate 39

NOx Rate (lb/hr) 536 519 1249 1325 1652 1688 1778 895 1174 1266 1060 40

NOx Rate (lb/MMBtu) 0.45 0.44 0.51 0.37 0.26 0.27 0.27 0.52 0.52 0.37 0.26 41

NOx (TPY) 2188 2161 4913 5070 6051 6293 6375 3553 4337 4544 4615 42

Controlled Rate 43

NOx Rate (lb/hr) 236 236 528 511 1227 1199 1279 366 474 1142 775 44

NOx Rate (lb/MMBtu) 0.20 0.20 0.22 0.14 0.19 0.19 0.19 0.21 0.21 0.33 0.19 45

NOx (TPY) 962 981 2077 1956 4495 4470 4586 1453 1752 4101 3376 46

47

Tons/Year Removed 1226 1180 2837 3114 1556 1823 1789 2100 2586 442 1239 48

49

Total Cost/year $1,214,000 $1,441,146 $1,699,807 $767,342 $2,268,806 $2,268,806 $2,268,806 $932,466 $883,900 $106,393 $1,272,427 TPC*CR+(FOM*MW)+VOM(MW*8760)*CF 50

$/Ton $990 $1,221 $599 $246 $1,458 $1,244 $1,268 $444 $342 $240 $1,027 51

Data from 2008 Addendum to BART report by CH2M Hill or July 

2008 report by Black & Veatch used when available and shown in 

red, else developed from IPM algorithms. Costs adjusted for 

owner's costs and AFUDC. For DJ 3&4, N 1&2, and W 1, 

adjustment for AFUDC and Owner's cost is per factors in 

Appendices of Dec 2007 documents

black is per IPM algorithm, red is calcuated from input cost
BASE COSTS

Control Scenario Boiler Type TECHNOLOGY VOM

mills/kwhr)

1.00 Wall-Fired LNB 0.07

2.00 Wall-Fired LNBO 0.09

3.00 Wall-Fired OFA 0.09

4.00 T-Fired LNC1 0.00

5.00 T-Fired LNC2 0.03

6.00 T-Fired LNC3 0.03

7.00 T-Fired LNC1_3 0.03

0.00 0.00

Note: percent reduction in this table was not used because actual or projected emissions data was available for each unit

Variable Designation Units Calculation

Unique ID 4158_BW43 4162_1 4162_2

Plant Dave Johnston Naughton Naughton

Unit BW43 1 2

Unit Size A MW 220 160 210 user input

Gross Heat Rate C Btu/kwhr 11097.8 10848.17 10707.82 user input

NOx Rate D lb/Mmbtu 0.511566667 0.515466667 0.522066667 user input

CF J % 89.81% 90.68% 84.36% user input

NOx Controls LNBO LNC3 LNC3

Retrofit Factor B 1.00 1.00 1.00 1 = typical retrofit

Heat Input I Btu/hr 2.44E+09 1.74E+09 2.25E+09 A*C*1000

NOx Removal Eff K % 57.73% 59.10% 59.61% from Plant Data Sheet

NOx Removed M lb/hr 721.08 528.75 699.84 D*I/10^6*K

Aux Power Cost T $/kwh 0.02 0.02 0.02

Steam Cost U $/Klb 4.00 4.00 4.00

Operating Labor Rate V $/hr 60.00 60.00 60.00 Total Labor Cost

March 2008 reported cost, including AFUDC and Owner's cost 17500000 9,600,000 9,100,000 From March 2008 Addendum

TPC ($) (excluding AFUDC and Owners cost) = 15,976,696 8,764,359 8,307,882 Total project cost

Base Cost (from IPM algorithm) 0 0 0

TPC ($/kw) = 72.6 54.8 39.6

Fixed O&M Cost

FOM ($/kw-yr) = Total Fixed O&M Cost LR Fixed O&M from July 2008 Black & Veatch, DJ 3&4, N & W from WY SIP Attachments, else IPM

VOM ($/MWhr) = Total Variable O&M Cost LR var O&M from July 2008 Black & Veatch, DJ 3&4, N & W from WY SIP Attachments, else IPM

Adjusted year 17 17 17

CR = 10.24% 10.24% 10.24%

Property Taxes and Insurance 1.20% 1.20% 1.20%

Total Charge Rate 11.44% 11.44% 11.44%

Cost of control - $/Ton

CF 90% 91% 84%

Control Efficiency 58% 59% 60%

Uncontrolled Rate

NOx Rate (lb/hr) 1249 895 1174

NOx Rate (lb/MMBtu) 0.51 0.52 0.52

NOx (TPY) 4913 3553 4337

Controlled Rate

NOx Rate (lb/hr) 528 366 474

NOx Rate (lb/MMBtu) 0.22 0.21 0.21

NOx (TPY) 2077 1453 1752

Tons/Year Removed 2837 2100 2586

Total Cost/year $1,828,137 $1,002,863 $950,631 TPC*CR+(FOM*MW)+VOM(MW*8760)*CF

$/Ton $644 $478 $368

Data from 2008 Addendum to BART report by CH2M Hill or July 2008 

report by Black & Veatch used when available and shown in red, else 

developed from IPM algorithms. Costs adjusted for owner's costs 

and AFUDC. For DJ 3&4, N 1&2, and W 1, adjustment for AFUDC and 

Owner's cost is per factors in Appendices of Dec 2007 documents

black is per IPM algorithm, red is calcuated from input cost
Variable Designation Units Value Calculation

Unique ID 4158_BW41 4158_BW42 4158_BW43 4158_BW44 6204_1 6204_2 6204_3 4162_1 4162_2 4162_3 6101_BW91

Plant Dave Johnston Dave Johnston Dave Johnston Dave Johnston Laramie River Laramie River Laramie River Naughton Naughton Naughton Wyodak

Unit BW41 BW42 BW43 BW44 1 2 3 1 2 3 BW91

Unit Size A MW 106 106 220 330 565 570 570 160 210 330 335

Heat Rate C Btu/kwhr 11120.94 11111.77 11097.8 10963.53 11312 10953 11686 10848.17 10707.82 10489.42 12068.4

NOx Rate D lb/Mmbtu 0.20 0.20 0.22 0.14 0.19 0.19 0.19 0.21 0.21 0.33 0.19

CF I % 93.14% 95.08% 89.81% 87.36% 83.62% 85.13% 81.86% 90.68% 84.36% 81.97% 99.40%

Type of fuel prb prb prb prb prb prb prb prb prb prb prb PRB assumed for conservativeness

Coal Factor F 1.05 1.05 1.05 1.05 1.05 1.05 1.05 1.05 1.05 1.05 1.05 Bit=1; PRB=1.05; Lig=1.07; gas=1 

Retrofit Factor B 1 1 1 1 1 1 1 1 1 1 1 1 = typical retrofit

HR Factor G 1.112094 1.111177 1.10978 1.096353 1.1312 1.0953 1.1686 1.084817 1.070782 1.048942 1.20684 C/10000

Heat Input H Btu/hr 1.18E+09 1.18E+09 2.44E+09 3.62E+09 6.39E+09 6.24E+09 6.66E+09 1.74E+09 2.25E+09 3.46E+09 4.04E+09 A*C*1000

NOx Removal Eff J % 25% 25% 25% 20% 20% 20% 20% 25% 25% 30% 20% percent reduction will be lower at lower NOx levels

NOx Removed K lb/hr 5.89E+01 5.89E+01 1.32E+02 1.02E+02 2.45E+02 2.40E+02 2.56E+02 9.15E+01 1.19E+02 3.43E+02 1.55E+02 D*H/10^6*j

Chem. Utilization UF 25.0% 25.0% 25.0% 25.0% 12.0% 12.0% 12.0% 25.0% 25.0% 25.0% 25.0%

Urea rate (100%) L lb/hr 153.76 153.63 344.30 266.72 1333.94 1303.04 1390.24 238.66 309.19 893.97 404.55 K/UF/46*30

Water Required M lb/hr 1384 1383 3099 2401 12005 11727 12512 2148 2783 8046 3641 L*9

Aux. Power N % 0.05 0.05 0.05 0.05 0.05 0.05 0.05 0.05 0.05 0.05 0.05

Dilution water rate O (1000gph) 0.166 0.166 0.372 0.288 1.441 1.407 1.501 0.258 0.334 0.965 0.437 M*0.12/1000 http://www.epa.gov/airmarkets/progsregs/epa-ipm/BaseCasev410.html#documentation

Urea Cost (50% sol) P $/ton 450 450 450 450 450 450 450 450 450 450 450

Aux Power Cost Q $/kwh 0.0201 0.0201 0.0201 0.0201 0.015 0.015 0.015 0.0227 0.0227 0.0227 0.016

Dilution water Cost R $/Kgal 1 1 1 1 1 1 1 1 1 1 1

Operating Labor Rate S $/hr 60 60 60 60 60 60 60 60 60 60 60 Total Labor Cost

Includes equipment, inatallation,buildings,electrical, retrofit difficulty

BMS ($) = 1755694 1755694 3643892 5465839 2650104 3478261 5465839 5548654 SNCR

BMA ($) = APH (SO@> 3lb/Mmbtu); 65000*B*(A*G)^.78

BMB ($) = BOP

BM ($) = 1,755,694 1,755,694 3,643,892 5,465,839 2,650,104 3,478,261 5,465,839 5,548,654 Total base cost

BM ($/KW) = 17 17 17 17 17 17 17 17

Total Project Cost

A1 = 5% of BM ($) = 87785 87785 182195 273292 132505 173913 273292 277433 Eng. and Construction management

A2 = 5% of BM ($) = 87785 87785 182195 273292 132505 173913 273292 277433 Labor adjustment

A3 = 5% of BM ($) = 87785 87785 182195 273292 132505 173913 273292 277433 Contractor profit/fees

CECC ($) = 2,019,048 2,019,048 4,190,476 6,285,714 3,047,619 4,000,000 6,285,714 6,380,952 Cap., Eng. and management 

CECC ($/kw) = 19 19 19 19 19 19 19 19

B1 = 5% of CECC 100,952 100,952 209,524 314,286 152,381 200,000 314,286 319,048 owners cost

TPC ($) = 2,120,000 2,120,000 4,400,000 6,600,000 16,878,000 16,878,000 16,878,000 3,200,000 4,200,000 6,600,000 6,700,000 Total project cost

TPC ($/kw) = 20 20 20 20 29.9 29.6 29.6 20 20 20 20 It was assumed that SNCR capital cost was $20/kW per 2008 ICAC White Paper on SNCR

For Laramie River, due to high furnace temp, a more costly injection system is assumed and LRS estimated cost was accepted

Fixed O&M Cost

FOMO ($/kw-yr) = 0.58868 0.58868 0.28364 0.18909 0.11044 0.10947 0.10947 0.39000 0.29714 0.18909 0.18627 fixed O&M - additional labor cost

FOMM ($/kw-yr) = 0.20 0.20 0.20 0.20 0.00 0.00 0.00 0.20 0.20 0.20 0.20 fixed O&M - additional maintenace, mtl and labor cost

FOM ($/kw-yr) = 0.79 0.79 0.48 0.39 0.11 0.11 0.11 0.59 0.50 0.39 0.39 Total Fixed O&M Cost

Variable O&M Cost

VOMR ($/MWhr) = 0.65 0.65 0.70 0.36 1.06 1.03 1.10 0.67 0.66 1.22 0.54 Variable O&M - urea 

VOMM ($/MWhr) = 0.0002 0.0002 0.0001 0.0001 0.0000 0.0000 0.0000 0.0001 0.0001 0.0001 0.0013 Variable O&M - dilution water corrected from previous estimate

VOMP ($/MWhr)= Variable O&M Power 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 This is not included in the S&L calculations, but should be changed value for cost of auxiliary power

VOM ($/MWhr) = 0.66 0.66 0.71 0.37 1.07 1.04 1.11 0.68 0.67 1.23 0.55 Total Variable O&M Cost

CR = 9.44% 9.44% 9.44% 9.44% 9.44% 9.44% 9.44% 9.44% 9.44% 9.44% 9.44%

Property Taxes and Insurance 1.20% 1.20% 1.20% 1.20% 1.20% 1.20% 1.20% 1.20% 1.20% 1.20% 1.20%

Total Charge Rate 10.64% 10.64% 10.64% 10.64% 10.64% 10.64% 10.64% 10.64% 10.64% 10.64% 10.64%

Cost of control - $/Ton

CF 93% 95% 90% 87% 84% 85% 82% 91% 84% 82% 99%

Control Efficiency 25% 25% 25% 20% 20% 20% 20% 25% 25% 30% 20%

Uncontrolled Rate (lb/Mbtu*Heat Input)/1000000

NOx Rate (lb/hr) 236 236 528 511 1227 1199 1279 366 474 1142 775 Lb/hr*8760*CF/2000

NOx Rate (lb/MMBtu) 0.2 0.2 0.216226081 0.1413 0.192015571 0.192015571 0.192015571 0.210837578 0.210837578 0.33 0.191788083

NOx (TPY) 962 981 2077 1956 4495 4470 4586 1453 1752 4101 3376

Controlled Rate

NOx Rate (lb/hr) 177 177 396 409 982 959 1023 274 356 800 620

NOx Rate (lb/MMBtu) 0.15 0.15 0.16 0.11 0.15 0.15 0.15 0.16 0.16 0.23 0.15 TPC*CR+(FOM*MW)+VOM(MW*8760)*CF

NOx (TPY) 721 736 1558 1565 3596 3576 3669 1090 1314 2871 2701

Tons/Year Removed 240 245 519 391 899 894 917 363 438 1230 675

Total Cost/year $882,430 $893,877 $1,810,782 $1,774,258 $6,286,091 $6,262,825 $6,375,033 $1,302,361 $1,596,932 $3,745,984 $2,454,146

$/Ton $3,670 $3,645 $3,488 $4,535 $6,993 $7,006 $6,951 $3,584 $3,647 $3,045 $3,635

Note: Capital Cost equations were modified to be a constant 

$20/kWe
Variable Designation Units Calculation

Unique ID 4158_BW43 4162_1 4162_2

Plant Dave Johnston Naughton Naughton

Unit BW43 1 2

Unit Size A MW 220 160 210

Heat Rate C Btu/kwhr 11097.8 10848.17 10707.82

NOx Rate D lb/Mmbtu 0.22 0.21 0.21

CF I % 89.81% 90.68% 84.36%

Type of fuel prb prb prb PRB assumed for conservativeness

Coal Factor F 1.05 1.05 1.05 Bit=1; PRB=1.05; Lig=1.07; gas=1 

Retrofit Factor B 1 1 1 1 = typical retrofit

HR Factor G 1.10978 1.084817 1.070782 C/10000

Heat Input H Btu/hr 2.44E+09 1.74E+09 2.25E+09 A*C*1000

NOx Removal Eff J % 25% 25% 25% percent reduction will be lower at lower NOx levels

NOx Removed K lb/hr 1.32E+02 9.15E+01 1.19E+02 D*H/10^6*j

Chem. Utilization UF 25.0% 25.0% 25.0%

Urea rate (100%) L lb/hr 344.30 238.66 309.19 K/UF/46*30

Water Required M lb/hr 3099 2148 2783 L*9

Aux. Power N % 0.05 0.05 0.05

Dilution water rate O (1000gph) 0.372 0.258 0.334 M*0.12/1000 http://www.epa.gov/airmarkets/progsregs/epa-ipm/BaseCasev410.html#documentation

Urea Cost (50% sol) P $/ton 450 450 450

Aux Power Cost Q $/kwh 0.0201 0.0227 0.0227

Dilution water Cost R $/Kgal 1 1 1

Operating Labor Rate S $/hr 60 60 60 Total Labor Cost

Includes equipment, inatallation,buildings,electrical, retrofit difficulty

BMS ($) = 3643892 2650104 3478261 SNCR

BMA ($) = APH (SO@> 3lb/Mmbtu); 65000*B*(A*G)^.78

BMB ($) = BOP

BM ($) = 3,643,892 2,650,104 3,478,261 Total base cost

BM ($/KW) = 17 17 17

Total Project Cost

A1 = 5% of BM ($) = 182195 132505 173913 Eng. and Construction management

A2 = 5% of BM ($) = 182195 132505 173913 Labor adjustment

A3 = 5% of BM ($) = 182195 132505 173913 Contractor profit/fees

CECC ($) = 4,190,476 3,047,619 4,000,000 Cap., Eng. and management 

CECC ($/kw) = 19 19 19

B1 = 5% of CECC - - - owners cost included in 10% engineering per CCM

TPC ($) = 4,400,000 3,200,000 4,200,000 Total project cost

TPC ($/kw) = 20 20 20 It was assumed that SNCR capital cost was $20/kW per 2008 ICAC White Paper on SNCR

Fixed O&M Cost

FOMO ($/kw-yr) = 0.28364 0.39000 0.29714 fixed O&M - additional labor cost

FOMM ($/kw-yr) = 0.20 0.20 0.20 fixed O&M - additional maintenace, mtl and labor cost

FOM ($/kw-yr) = 0.48 0.59 0.50 Total Fixed O&M Cost

Variable O&M Cost

VOMR ($/MWhr) = 0.70 0.67 0.66 Variable O&M - urea 

VOMM ($/MWhr) = 0.0001 0.0001 0.0001 Variable O&M - dilution water corrected from previous estimate

VOMP ($/MWhr)= Variable O&M Power 0.01 0.01 0.01 This is not included in the S&L calculations, but should be changed value for cost of auxiliary power

VOM ($/MWhr) = 0.71 0.68 0.67 Total Variable O&M Cost

Life, yrs 9 11 11

CR = 15.35% 13.34% 13.34%

Property Taxes and Insurance 1.20% 1.20% 1.20%

Total Charge Rate 16.55% 14.54% 14.54%

Cost of control - $/Ton

CF 90% 91% 84%

Control Efficiency 25% 25% 25%

Uncontrolled Rate (lb/Mbtu*Heat Input)/1000000

NOx Rate (lb/hr) 528 366 474 Lb/hr*8760*CF/2000

NOx Rate (lb/MMBtu) 0.22 0.21 0.21

NOx (TPY) 2077 1453 1752

Controlled Rate

NOx Rate (lb/hr) 396 274 356

NOx Rate (lb/MMBtu) 0.16 0.16 0.16 TPC*CR+(FOM*MW)+VOM(MW*8760)*CF

NOx (TPY) 1558 1090 1314

Tons/Year Removed 519 363 438

Total Cost/year $2,070,793 $1,427,046 $1,760,581

$/Ton $3,988 $3,927 $4,020

Note: Capital Cost equations were modified to be a constant 

$20/kWe
Variable Designation Units Value Calculation

Unique ID 4158_BW41 4158_BW42 4158_BW43 4158_BW43 4158_BW44 6204_1 6204_2 6204_3 6204_1 6204_2 6204_3 4162_1 4162_2 4162_1 4162_2 4162_3 6101_BW91

Plant Dave Johnston Dave Johnston Dave Johnston Dave Johnston Dave Johnston Laramie River Laramie River Laramie River Laramie River Laramie River Laramie River Naughton Naughton Naughton Naughton Naughton Wyodak

Unit BW41 BW42 BW43 BW43 BW44 1 2 3 1 2 3 1 2 1 2 3 BW91

Unit Size A MW 106 106 220 220 330 565 570 570 565 570 570 160 210 160 210 330 335

Altitude 4950 4950 4950 4950 4950 4750 4750 4750 4750 4750 4750 6939 6939 6939 6939 6939 4420

Altitude adj (gas volume at elevation/sea level gas volume) 1.24 1.24 1.24 1.24 1.24 1.23 1.23 1.23 1.23 1.23 1.23 1.35 1.35 1.35 1.35 1.35 1.21 = 1/ exp(-altitude in meters/7000 meters), from http://www.regentsprep.org/regents/math/algtrig/ATP8b/exponentialResource.htm

Gross Heat Rate C Btu/kwhr 11120.94 11111.77 11097.8 11097.8 10963.53 11312 10953 11686 11312 10953 11686 10848.17 10707.82 10848.17 10707.82 10489.42 12068.4

NOx Rate D lb/Mmbtu 0.20 0.20 0.22 0.22 0.14 0.19 0.19 0.19 0.19 0.19 0.19 0.21 0.21 0.21 0.21 0.33 0.19

CF J CF 93.1% 95.1% 89.8% 89.8% 87.4% 83.6% 85.1% 81.9% 83.6% 85.1% 81.9% 90.7% 84.4% 90.7% 84.4% 82.0% 99.4%

Type of Coal F prb prb prb prb prb prb prb prb prb prb prb prb prb prb prb prb prb blends are treated as PRB to be conservative

Coal Factor G 1.05 1.05 1.05 1.05 1.05 1.05 1.05 1.05 1.05 1.05 1.05 1.05 1.05 1.05 1.05 1.05 1.05 Bit=1; PRB=1.05; Lig=1.07

Retrofit Factor B 1.5 1.5 1.5 1.5 1.5 1 1.2 1 1 1.2 1 1.3 1.3 1.3 1.3 1.3 1.3 1 = typical retrofit

HR Factor H 1.112094 1.111177 1.10978 1.10978 1.096353 1.1312 1.0953 1.1686 1.1312 1.0953 1.1686 1.084817 1.070782 1.084817 1.070782 1.048942 1.20684 C/10000

Heat Input I Btu/hr 1.18E+09 1.18E+09 2.44E+09 2.44E+09 3.62E+09 6.39E+09 6.24E+09 6.66E+09 6.39E+09 6.24E+09 6.66E+09 1.74E+09 2.25E+09 1.74E+09 2.25E+09 3.46E+09 4.04E+09 A*C*1000

CF J 93.1% 95.1% 89.8% 89.8% 87.4% 83.6% 85.1% 81.9% 83.6% 85.1% 81.9% 90.7% 84.4% 90.7% 84.4% 82.0% 99.4% read from Plant Data table

NOx Removal Eff K % 75.0% 75.0% 76.9% 76.9% 64.6% 74.0% 74.0% 74.0% 74.0% 74.0% 74.0% 76.3% 76.3% 76.3% 76.3% 84.8% 73.9% for NOx>0.5lb/Mbtu=90%; <.5 = (NOx-0.05)/NOx

NOx Removal factor L 0.94 0.94 0.96 0.96 0.81 0.92 0.92 0.92 0.92 0.92 0.92 0.95 0.95 0.95 0.95 1.06 0.92

NOx Removed M lb/hr 1.77E+02 1.77E+02 4.06E+02 4.06E+02 3.30E+02 9.08E+02 8.87E+02 9.46E+02 9.08E+02 8.87E+02 9.46E+02 2.79E+02 3.62E+02 2.79E+02 3.62E+02 9.69E+02 5.73E+02 D*I/10^6*K

Ammonia rate (anhydrous) N lb/hr 69 69 157 157 128 352 344 367 352 344 367 108 140 108 140 376 400

M*1.05*17/46 this assumes the stoichiometric 

rate for the level of reduction, plus 5%

Steam Required O lb/hr 78 77 178 178 145 398 389 415 398 389 415 122 159 122 159 425 453 N*1.13

Aux. Power P % 0.60 0.60 0.60 0.60 0.59 0.60 0.59 0.61 0.60 0.59 0.61 0.59 0.59 0.59 0.59 0.58 0.62 0.56*(G*H)^0.43

Ammonia cost R $/ton 625 625 625 625 625 625 625 625 625 625 625 625 625 625 625 625 625

Catalyst Cost S $/m3 5500 5500 5500 5500 5500 5500 5500 5500 5500 5500 5500 5500 5500 5500 5500 5500 5500

Aux Power Cost T $/kwh 0.0201 0.0201 0.0201 0.0201 0.0201 0.015 0.015 0.015 0.015 0.015 0.015 0.0227 0.0227 0.0227 0.0227 0.0227 0.016

Steam Cost U $/Klb 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4

Operating Labor Rate V $/hr 60 60 60 60 60 60 60 60 60 60 60 60 60 60 60 60 60 Total Labor Cost

Capital Cost Calculation (includes equipment, installation, buildings, foundations,electrical, minor physical/chemical ww treatment and retrofit difficulty)

BMR ($) = SCR 27,327,620 27,306,888 53,661,524 72,100,000 74,423,639 85,358,765 100,245,263 88,667,565 112,200,688 119,145,874 118,470,636 36,721,398 46,598,034 66,500,000 66,100,000 70,789,030 71,856,399 modified to incorporate altitude adjustment Comments (LRS Attach to Exh 14, p 2,3)

BMF ($) = base reagent preparation cost 1,495,094 1,494,786 1,840,236 1,747,904 2,250,426 2,237,277 2,273,804 3,843,099 3,843,099 3,843,099 1,675,907 1,787,972 2,287,651 2,006,169 Comments (LRS Attach to Exh 14, p 2,3)

BMA ($) = APH (SO@> 3lb/Mmbtu)

BMB ($) = fans/aux power 4,719,204 4,717,569 6,407,342 7,558,157 6,375,838 7,576,052 6,487,501 - - - 4,988,830 5,561,926 6,666,688 6,797,350 modified to incorporate altitude adjustment

Scaffolding 4,059,157 4,059,157 4,059,157 Comments (LRS Attach to Exh 14, p 4)

OT 5-10 LRS - Not allowed - assumed in base cost

OT 6-10 LRS - Not allowed - assumed in base cost

Per Diem LRS - Not allowed - assumed in base cost

Consumables 579,880 579,880 579,880 Comments (LRS Attach to Exh 14, p 4)

Freight 2,520,311 2,520,311 2,520,311 Comments (LRS Attach to Exh 14, p 4)

Contractor's G&A Included in Profit and Fees

Contractor's Profit and Fees $12,320,313 $13,014,832 $12,947,308 LRS: Adjusted to 10% of costs, per IPM

DC = Total Direct Cost 72,100,000 135,523,447 143,163,152 142,420,390 66,500,000 66,100,000 DJ 3, N1, N2: from company comments

DC ($/KW) = 328 240 251 250 416 315

 421,106,990

382,824,536

Total Project Cost

A1 = 10% of BM ($) = Eng. and Construction management 3,354,192 3,351,924 6,190,910 8,372,970 9,398,503 11,005,859 9,742,887 4,338,614 5,394,793 7,974,337 8,065,992

A2 = 10% of BM ($) = Labor adjustment 3,354,192 3,351,924 6,190,910 8,372,970 9,398,503 11,005,859 9,742,887 4,338,614 5,394,793 7,974,337 8,065,992

A3 = 10% of BM ($) = Contractor profit/fees 3,354,192 3,351,924 6,190,910 8,372,970 9,398,503 11,005,859 9,742,887 4,338,614 5,394,793 7,974,337 8,065,992

Indirect Costs 421,106,990

A1 = 5% of DC($) = General Facilities - - - - Included in itemized cost

A2 = 10% of DC ($) = Engineering and Home Office 7,210,000 13,552,345 14,316,315 14,242,039 6,650,000 6,610,000

A3 = 0% of DC ($) = Process Contingency - - - - - - For SCR, which is very well established technology, Process Contingency should be zero

Total Cost 79,310,000 149,075,792 157,479,467 156,662,429 73,150,000 72,710,000

$361 $264 $276 $275 $457 $346

Project Contingency - - - - - - Zero because of comprehensive and conservative company estimates

AFUDC - - - - - - Not allowed, per CCM

Preproduction Cost 1,586,200 2,981,516 3,149,589 3,133,249 1,463,000 1,454,200

Inventory Capital - - - - - - From company comments

Initial Catalyst and Chemicals 35,000 7,079,000 7,079,000 7,524,000 35,000 35,000 From company comments

BM ($) = Total base cost 33,541,918 33,519,243 61,909,102 83,729,700 93,985,029 110,058,592 97,428,871 159,136,572 167,708,333 167,319,953 43,386,135 53,947,932 74,648,457 74,199,546 79,743,368 80,659,918

BM ($/KW) = 316 316 281 254 166 193 171 282 294 294 271 257 467 353 242 241

 301,472,492 494,164,857

CECC ($) = Cap., Eng. and management 44,720,730 44,690,498 82,542,097 111,635,039 125,308,253 146,738,795 129,899,855 159,136,572 167,708,333 167,319,953 57,845,818 71,927,637 74,648,457 74,199,546 106,320,148 107,542,164

CECC ($/kw) = 422 422 375 338 222 257 228 282 294 294 362 343 467 353 322 321

 401,946,903

B1 = 5% of CECC owners cost - - - - - - - - - - - - - - Owner's cost included in 10% engineering per CCM

B2 = 6% of CECC + B1 AFUDC (2yr cycle) - - - - - - - - - - - - - - Not allowed, per CCM

TPC ($) = Total project cost 44,720,730 44,690,498 82,542,097 80,931,561 111,635,039 125,308,253 146,738,795 129,899,855 159,136,572 167,708,333 167,319,953 57,845,818 71,927,637 74,648,457 74,199,546 106,320,148 107,542,164

TPC ($/kw) = $422 $422 $375 $368 $338 $222 $257 $228 $282 $294 $294 $362 $343 $467 $353 $322 $321

Fixed O&M Cost

FOMO ($/kw-yr) = fixed O&M - additional labor cost 0.6 0.6 0.3 0.3 0.2 0.1 0.1 0.1 0.1 0.1 0.1 0.4 0.3 0.4 0.3 0.2 0.2

FOMM ($/kw-yr) = fixed O&M - additional maintenace, mtl and labor cost 2.8 2.8 1.4 1.4 0.9 0.5 0.5 0.5 0.5 0.5 0.5 1.9 1.4 1.9 1.4 0.9 0.9

FOM ($/kw-yr) = Total Fixed O&M Cost 3.42 3.42 1.65 1.65 1.10 0.64 0.64 0.64 0.64 0.64 0.64 2.27 1.73 2.27 1.73 1.10 1.08

Variable O&M Cost

VOMR ($/MWhr) = Variable O&M - ammonia 0.20 0.20 0.22 0.22 0.12 0.19 0.19 0.20 0.19 0.19 0.20 0.21 0.21 0.21 0.21 0.36 0.37 changed from urea to ammonia

VOMW ($/MWhr) = Variable O&M - catalyst 0.22 0.22 0.23 0.23 0.21 0.25 0.24 0.25 0.25 0.24 0.25 0.23 0.25 0.23 0.25 0.28 0.21 See pdf pg 10/79 at http://www.epa.gov/airmarkets/progsregs/epa-ipm/docs/SuppDoc410MATS.pdf

VOMP ($/MWhr)= Variable O&M Power 0.12 0.12 0.12 0.12 0.12 0.09 0.09 0.09 0.09 0.09 0.09 0.13 0.13 0.13 0.13 0.13 0.10 This is not included in the S&L calculations, but should be changed value for cost of auxiliary power

VOMM ($/MWhr) = Variable O&M - steam 0.003 0.003 0.003 0.003 0.002 0.003 0.003 0.003 0.003 0.003 0.003 0.003 0.003 0.003 0.003 0.005 0.005

VOM ($/MWhr) = Total Variable O&M Cost 0.55 0.54 0.58 0.58 0.46 0.53 0.52 0.55 0.53 0.52 0.55 0.58 0.59 0.58 0.59 0.77 0.68

CR = 9.44% 9.44% 9.44% 9.44% 9.44% 9.44% 9.44% 9.44% 9.44% 9.44% 9.44% 9.44% 9.44% 9.44% 9.44% 9.44% 9.44%

Property Taxes and Insurance 1.20% 1.20% 1.20% 1.20% 1.20% 1.20% 1.20% 1.20% 1.20% 1.20% 1.20% 1.20% 1.20% 1.20% 1.20% 1.20% 1.20%

Total Charge Rate 10.64% 10.64% 10.64% 10.64% 10.64% 10.64% 10.64% 10.64% 10.64% 10.64% 10.64% 10.64% 10.64% 10.64% 10.64% 10.64% 10.64%

Cost of control - $/Ton

CF 93% 95% 90% 90% 87% 84% 85% 82% 84% 85% 82% 91% 84% 91% 84% 82% 99%

Control Efficiency 75% 75% 77% 77% 65% 74% 74% 74% 74% 74% 74% 76% 76% 76% 76% 85% 74%

Uncontrolled Rate (lb/Mbtu*Heat Input)/1000000

NOx Rate (lb/hr) Lb/hr*8760*CF/2000 236 236 528 528 511 1227 1199 1279 1227 1199 1279 366 474 366 474 1142 775

NOx Rate (lb/MMBtu) 0.200 0.200 0.216 0.216 0.141 0.192 0.192 0.192 0.192 0.192 0.192 0.211 0.211 0.211 0.211 0.330 0.192

NOx (TPY) 962 981 2077 2077 1956 4495 4470 4586 4495 4470 4586 1453 1752 1453 1752 4101 3376

Controlled Rate

NOx Rate (lb/hr) 58.9 58.9 122.1 122.1 180.9 319.6 312.2 333.1 319.6 312.2 333.1 86.8 112.4 86.8 112.4 173.1 202.1

NOx Rate (lb/MMBtu) TPC*CR+(FOM*MW)+VOM(MW*8760)*CF 0.05 0.05 0.05 0.05 0.05 0.05 0.05 0.05 0.05 0.05 0.05 0.05 0.05 0.05 0.05 0.05 0.05

NOx (TPY) 240 245 480 480 692 1170 1164 1194 1170 1164 1194 345 415 345 415 621 880

Tons/Year Removed 721 736 1597 1597 1264 3324 3306 3392 3324 3306 3392 1109 1336 1109 1336 3480 2496

Total Cost/year $5,594,374 $5,596,824 $10,151,687 $9,980,337 $13,391,557 $15,902,235 $18,191,651 $16,416,942 $19,501,329 $20,422,662 $20,398,176 $7,254,468 $8,937,135 $9,042,150 $9,178,850 $13,498,309 $13,801,075

$/Ton $7,755 $7,607 $6,359 $6,251 $10,595 $4,784 $5,503 $4,840 $5,866 $6,178 $6,014 $6,543 $6,688 $8,155 $6,869 $3,879 $5,530

 equals K/80% based upon 8/10/12 email from Sargent & Lundy, and See pdf pg 10/79 at 

http://www.epa.gov/airmarkets/progsregs/epa-ipm/docs/SuppDoc410MATS.pdf
Variable Designation Units Calculation

Unique ID 4158_BW43 4162_1 4162_2

Plant Dave Johnston Naughton Naughton

Unit BW43 1 2

Unit Size A MW 220 160 210

Altitude 4950 6939 6939

Altitude adj (gas volume at elevation/sea level gas volume) 1.24 1.35 1.35 = 1/ exp(-altitude in meters/7000 meters), from http://www.regentsprep.org/regents/math/algtrig/ATP8b/exponentialResource.htm

Gross Heat Rate C Btu/kwhr 11097.8 10848.17 10707.82

NOx Rate D lb/Mmbtu 0.22 0.21 0.21

CF J CF 89.8% 90.7% 84.4%

Type of Coal F prb prb prb blends are treated as PRB to be conservative

Coal Factor G 1.05 1.05 1.05 Bit=1; PRB=1.05; Lig=1.07

Retrofit Factor B 1.5 1.3 1.3 1 = typical retrofit

HR Factor H 1.10978 1.084817 1.070782 C/10000

Heat Input I Btu/hr 2.44E+09 1.74E+09 2.25E+09 A*C*1000

CF J 89.8% 90.7% 84.4% read from Plant Data table

NOx Removal Eff K % 76.9% 76.3% 76.3% for NOx>0.5lb/Mbtu=90%; <.5 = (NOx-0.05)/NOx

NOx Removal factor L 0.96 0.95 0.95

NOx Removed M lb/hr 4.06E+02 2.79E+02 3.62E+02 D*I/10^6*K

Ammonia rate (anhydrous) N lb/hr 157 108 140

M*1.05*17/46 this assumes the stoichiometric 

rate for the level of reduction, plus 5%

Steam Required O lb/hr 178 122 159 N*1.13

Aux. Power P % 0.60 0.59 0.59 0.56*(G*H)^0.43

Ammonia cost R $/ton 625 625 625

Catalyst Cost S $/m3 5500 5500 5500

Aux Power Cost T $/kwh 0.0201 0.0227 0.0227

Steam Cost U $/Klb 4 4 4

Operating Labor Rate V $/hr 60 60 60 Total Labor Cost

Capital Cost Calculation (includes equipment, installation, buildings, foundations,electrical, minor physical/chemical ww treatment and retrofit difficulty)

BMR ($) = SCR 72,100,000 66,500,000 66,100,000 modified to incorporate altitude adjustment Comments (LRS Attach to Exh 14, p 2,3)

BMF ($) = base reagent preparation cost Comments (LRS Attach to Exh 14, p 2,3)

BMA ($) = APH (SO@> 3lb/Mmbtu)

BMB ($) = fans/aux power modified to incorporate altitude adjustment

DC = Total Direct Cost 72,100,000 66,500,000 66,100,000 DJ 3, N1, N2: from company comments

DC ($/KW) = 328 416 315

Indirect Costs

A1 = 5% of DC($) = General Facilities - Included in itemized cost

A2 = 10% of DC ($) = Engineering and Home Office 7,210,000 6,650,000 6,610,000

A3 = 0% of DC ($) = Process Contingency - - - For SCR, which is very well established technology, Process Contingency should be zero

Total Cost 79,310,000 73,150,000 72,710,000

$361 $457 $346

Project Contingency - - - Zero because of comprehensive and conservative company estimates

AFUDC - - - Not allowed, per CCM

Preproduction Cost 1,586,200 1,463,000 1,454,200

Inventory Capital - - - From company comments

Initial Catalyst and Chemicals 35,000 35,000 35,000 From company comments

B1 = 5% of CECC owners cost Owner's cost included in 10% engineering and home office per CCM

B2 = 6% of CECC + B1 AFUDC (2yr cycle) Not allowed, per CCM

TPC ($) = Total project cost 80,931,561 74,648,457 74,199,546

TPC ($/kw) = $368 $467 $353

Fixed O&M Cost

FOMO ($/kw-yr) = fixed O&M - additional labor cost 0.3 0.4 0.3

FOMM ($/kw-yr) = fixed O&M - additional maintenace, mtl and labor cost 1.4 1.9 1.4

FOM ($/kw-yr) = Total Fixed O&M Cost 1.65 2.27 1.73

Variable O&M Cost

VOMR ($/MWhr) = Variable O&M - ammonia 0.22 0.21 0.21

VOMW ($/MWhr) = Variable O&M - catalyst 0.23 0.23 0.25 See pdf pg 10/79 at http://www.epa.gov/airmarkets/progsregs/epa-ipm/docs/SuppDoc410MATS.pdf

VOMP ($/MWhr)= Variable O&M Power 0.12 0.13 0.13 This is not included in the S&L calculations, but should be changed value for cost of auxiliary power

VOMM ($/MWhr) = Variable O&M - steam 0.003 0.003 0.003

VOM ($/MWhr) = Total Variable O&M Cost 0.58 0.58 0.59

Lifetime 9.00 11.00 11.00

CR = 15.35% 13.34% 13.34%

Property Taxes and Insurance 1.20% 1.20% 1.20%

Total Charge Rate 16.55% 14.54% 14.54%

Cost of control - $/Ton

CF 90% 91% 84%

Control Efficiency 77% 76% 76%

Uncontrolled Rate (lb/Mbtu*Heat Input)/1000000

NOx Rate (lb/hr) Lb/hr*8760*CF/2000 528 366 474

NOx Rate (lb/MMBtu) 0.216 0.211 0.211

NOx (TPY) 2077 1453 1752

Controlled Rate

NOx Rate (lb/hr) 122.1 86.8 112.4

NOx Rate (lb/MMBtu) TPC*CR+(FOM*MW)+VOM(MW*8760)*CF 0.05 0.05 0.05

NOx (TPY) 480 345 415

Tons/Year Removed 1597 1109 1336

Total Cost/year $14,762,870 $11,950,751 $12,069,960

$/Ton $9,247 $10,779 $9,033

 equals K/80% based upon 8/10/12 email from Sargent & Lundy, and See pdf pg 10/79 at 

http://www.epa.gov/airmarkets/progsregs/epa-ipm/docs/SuppDoc410MATS.pdf
Reported Capital Cost Estimates from Owners

Unique ID 4158_BW41 4158_BW42 4158_BW43 4158_BW44 6204_1 6204_2 6204_3 4162_1 4162_2 6101_BW91

Plant Dave Johnston Dave Johnston Dave Johnston Dave Johnston Laramie River Laramie River Laramie River Naughton Naughton Naughton Wyodak

Unit BW41 BW42 BW43 BW44 1 2 3 1 2 3 BW91

Unit Size (MW) 106 106 220 330 565 570 570 160 210 330 335

Mar-08

LNB/OFA $17,500,000 $7,900,000 22096000 22096000 22096000 $9,600,000 $9,100,000 $0 $13,100,000

 $/kW $80 $24 $39 $39 $39 $60 $43 $0 $39

LNB/OFA and SNCR $24,035,544 $17,905,780 43441000 43441000 43441000 $17,526,855 $19,878,765 $19,495,654

 $/kW $109 $54 $77 $76 $76 $110 $95 $58

 $/kw difference from LNB/OFA $30 $30 $38 $37 $37 $50 $51 $19

LNB/OFA and SCR $129,700,000 $151,900,000 145197000 145197000 145197000 $94,600,000 $115,900,000 $136,800,000 $171,900,000

 $/kW $590 $460 $257 $255 $255 $591 $552 $415 $513

 $/kw difference from LNB/OFA $510 $436 $218 $216 $216 $531 $509 $415 $474

Dec-07

LNB/OFA $15,900,000 $7,800,000 $7,300,000 $7,500,000 $9,300,000

 $/kW $72 $24 $46 $36 $28

LNB/OFA and SNCR $24,000,000 $17,900,000 $17,500,000 $19,900,000 $14,520,327 $19,500,000

 $/kW $109 $54 $109 $95 $44 $58

 $/kw difference from LNB/OFA $37 $31 $49 $51 $44 $19

LNB/OFA and SCR $83,300,000 $106,700,000 $58,200,000 $73,000,000 $92,000,000 $108,300,000

 $/kW $379 $323 $364 $348 $279 $323

 $/kw difference from LNB/OFA $306 $300 $318 $312 $279 $296

average

Four Month Increase in SCR Costs 66% 46% 67% 63% 49% 60% 59%

2008 Cost, excl AFUDC and owners cost $467 $400 $193 $191 $191 $487 $466 $380 $434

Dec 2007 cost excl AFUDC $281 $275 $292 $286 $256 $271

Estimates from IPM Cost Model $422 $422 $375 $338 $282 $294 $294 $362 $343 $322 $321

Assumed Retrofit Factor 1.5 1.5 1.5 1.5 1 1.2 1 1.3 1.3 1.3 1.3

2013 costs $111,232,340 $241,470,000 $255,881,000 $249,555,000 $102,589,880 $101,976,860

$506 $427 $449 $438 $641 $486

65% 96% 108% 103% 102% 56%

7,684,123

Notes:

Data for Dave Johnston, Naughton, and Wyodak from Dec 2007 and March 2008 BART submittals. AFUDC and owner's cost adjustments based upon factors in Dec 2007 cost estimates

Data for Laramie River from July 24, 2008 submittal by Black & Veatch and May 28, 2009 WYDEQ BART Analysis. Per BART guidelines, AFUDC and owner's cost adjustments based upon factors in July 2008 submittal
DJ 1

Comb Control (CC) SNCR SCR CC and SNCR CC and SCR

Capital Cost, $/kW $95 $20 $422 $115 $517

Control Efficiency 56% 25% 75% 67% 89%

Uncontrolled Rate

NOx Rate (lb/hr) 536 236 236 536 536

NOx Rate (lb/MMBtu) 0.45 0.20 0.20 0.45 0.45

NOx (TPY) 2188 962 962 2188 2188

Controlled Rate

NOx Rate (lb/hr) 236 177 59 176.82 58.94

NOx Rate (lb/MMBtu) 0.20 0.15 0.05 0.15 0.05

NOx (TPY) 962 721 240 721.37 240.46

Tons/Year Removed 1226 240 721 1466.31 1947.23

Total Cost/year $1,214,000 $882,430 $5,594,374 $2,096,430 $6,808,374

$/Ton $990 $3,670 $7,755 $1,430 $3,496

$/ton Incremental $9,798 $3,670 $9,798

DJ 2

Comb Control (CC) SNCR SCR CC and SNCR CC and SCR

Capital Cost, $/kW $115 $20 $422 $135 $537

Control Efficiency 55% 25% 75% 66% 89%

Uncontrolled Rate

NOx Rate (lb/hr) 519 236 236 519 519

NOx Rate (lb/MMBtu) 0.44 0.20 0.20 0.44 0.44

NOx (TPY) 2161 981 981 2,161 2,161

Controlled Rate

NOx Rate (lb/hr) 236 177 59 177 59

NOx Rate (lb/MMBtu) 0.20 0.15 0.05 0.15 0.05

NOx (TPY) 981 736 245 736 245

Tons/Year Removed 1180 245 736 1,425 1,916

Total Cost/year $1,441,146 $893,877 $5,596,824 $2,335,022 $7,037,969

$/Ton $1,221 $3,645 $7,607 $1,638 $3,673

$/ton Incremental $9,588 $3,645 $9,588
DJ 3

Comb Control (CC) SNCR SCR CC and SNCR CC and SCR

Capital Cost, $/kW $73 $20 $375 $93 $448

Control Efficiency 58% 25% 77% 68% 90%

Uncontrolled Rate

NOx Rate (lb/hr) 1249 528 528 1249 1249

NOx Rate (lb/MMBtu) 0.51 0.22 0.22 0.51 0.51

NOx (TPY) 4913 2077 2077 4,913 4,913

Controlled Rate

NOx Rate (lb/hr) 528 396 122 396 122

NOx Rate (lb/MMBtu) 0.22 0.16 0.05 0.16 0.05

NOx (TPY) 2077 1558 480 1,558 480

Tons/Year Removed 2837 519 1597 3,356 4,433

Total Cost/year $1,699,807 $1,810,782 $10,151,687 $3,510,589 $11,851,494

$/Ton $599 $3,488 $6,359 $1,046 $2,673

$/ton Incremental $7,742 $3,488 $7,742

DJ 4

Comb Control (CC) SNCR SCR CC and SNCR CC and SCR

Capital Cost, $/kW $22 $20 $338 $42 $360

Control Efficiency 61% 20% 65% 69% 86%

Uncontrolled Rate

NOx Rate (lb/hr) 1325 511 511 1325 1325

NOx Rate (lb/MMBtu) 0.37 0.14 0.14 0.37 0.37

NOx (TPY) 5070 1956 1956 5,070 5,070

Controlled Rate

NOx Rate (lb/hr) 511 409 181 409 181

NOx Rate (lb/MMBtu) 0.14 0.11 0.05 0.11 0.05

NOx (TPY) 1956 1565 692 1,565 692

Tons/Year Removed 3114 391 1264 3,505 4,377

Total Cost/year $767,342 $1,774,258 $13,391,557 $2,541,600 $14,158,899

$/Ton $246 $4,535 $10,595 $725 $3,235

$/ton Incremental $13,312 $4,535 $13,312
DJ 1

Comb Control (CC) SNCR SCR CC and SNCR CC and SCR

Capital Cost, $/kW $95 $20 $422 $115 $517

Control Efficiency 56% 25% 75% 67% 89%

Uncontrolled Rate

NOx Rate (lb/hr) 536 236 236 536 536

NOx Rate (lb/MMBtu) 0.45 0.20 0.20 0.45 0.45

NOx (TPY) 2188 962 962 2188 2188

Controlled Rate

NOx Rate (lb/hr) 236 177 59 176.82 58.94

NOx Rate (lb/MMBtu) 0.20 0.15 0.05 0.15 0.05

NOx (TPY) 962 721 240 721.37 240.46

Tons/Year Removed 1226 240 721 1466.31 1947.23

Total Cost/year $1,214,000 $882,430 $5,594,374 $2,096,430 $6,808,374

$/Ton $990 $3,670 $7,755 $1,430 $3,496

$/ton Incremental $9,798 $3,670 $9,798

DJ 2

Comb Control (CC) SNCR SCR CC and SNCR CC and SCR

Capital Cost, $/kW $115 $20 $422 $135 $537

Control Efficiency 55% 25% 75% 66% 89%

Uncontrolled Rate

NOx Rate (lb/hr) 519 236 236 519 519

NOx Rate (lb/MMBtu) 0.44 0.20 0.20 0.44 0.44

NOx (TPY) 2161 981 981 2,161 2,161

Controlled Rate

NOx Rate (lb/hr) 236 177 59 177 59

NOx Rate (lb/MMBtu) 0.20 0.15 0.05 0.15 0.05

NOx (TPY) 981 736 245 736 245

Tons/Year Removed 1180 245 736 1,425 1,916

Total Cost/year $1,441,146 $893,877 $5,596,824 $2,335,022 $7,037,969

$/Ton $1,221 $3,645 $7,607 $1,638 $3,673

$/ton Incremental $9,588 $3,645 $9,588
DJ 3

Comb Control (CC) SNCR SCR CC and SNCR CC and SCR

Capital Cost, $/kW $73 $20 $368 $93 $440

Control Efficiency 58% 25% 77% 68% 90%

Uncontrolled Rate

NOx Rate (lb/hr) 1249 528 528 1249 1249

NOx Rate (lb/MMBtu) 0.51 0.22 0.22 0.51 0.51

NOx (TPY) 4913 2077 2077 4,913 4,913

Controlled Rate

NOx Rate (lb/hr) 528 396 122 396 122

NOx Rate (lb/MMBtu) 0.22 0.16 0.05 0.16 0.05

NOx (TPY) 2077 1558 480 1,558 480

Tons/Year Removed 2837 519 1597 3,356 4,433

Total Cost/year $1,699,807 $1,810,782 $9,980,337 $3,510,589 $11,680,144

$/Ton $599 $3,488 $6,251 $1,046 $2,635

$/ton Incremental $7,583 $3,488 $7,583

DJ 4

Comb Control (CC) SNCR SCR CC and SNCR CC and SCR

Capital Cost, $/kW $22 $20 $338 $42 $360

Control Efficiency 61% 20% 65% 69% 86%

Uncontrolled Rate

NOx Rate (lb/hr) 1325 511 511 1325 1325

NOx Rate (lb/MMBtu) 0.37 0.14 0.14 0.37 0.37

NOx (TPY) 5070 1956 1956 5,070 5,070

Controlled Rate

NOx Rate (lb/hr) 511 409 181 409 181

NOx Rate (lb/MMBtu) 0.14 0.11 0.05 0.11 0.05

NOx (TPY) 1956 1565 692 1,565 692

Tons/Year Removed 3114 391 1264 3,505 4,377

Total Cost/year $767,342 $1,774,258 $13,391,557 $2,541,600 $14,158,899

$/Ton $246 $4,535 $10,595 $725 $3,235

$/ton Incremental $13,312 $4,535 $13,312
DJ 3

Comb Control (CC) SNCR SCR CC and SNCR CC and SCR

Capital Cost, $/kW $73 $20 $368 $93 $440

Control Efficiency 58% 25% 77% 68% 90%

Uncontrolled Rate

NOx Rate (lb/hr) 1249 528 528 1249 1249

NOx Rate (lb/MMBtu) 0.51 0.22 0.22 0.51 0.51

NOx (TPY) 4913 2077 2077 4,913 4,913

Controlled Rate

NOx Rate (lb/hr) 528 396 122 396 122

NOx Rate (lb/MMBtu) 0.22 0.16 0.05 0.16 0.05

NOx (TPY) 2077 1558 480 1,558 480

Tons/Year Removed 2837 519 1597 3,356 4,433

Total Cost/year $1,828,137 $2,070,793 $14,762,870 $3,898,930 $16,591,006

$/Ton $644 $3,988 $9,247 $1,162 $3,742

$/ton Incremental $11,781 $3,988 $11,781
LR 1

Comb Control (CC) SNCR SCR CC and SNCR CC and SCR

Capital Cost, $/kW $37 $30 $282 $67 $319

Control Efficiency 26% 20% 74% 41% 81%

Uncontrolled Rate

NOx Rate (lb/hr) 1652 1227 1227 1652 1652

NOx Rate (lb/MMBtu) 0.26 0.19 0.19 0.26 0.26

NOx (TPY) 6051 4495 4495 6,051 6,051

Controlled Rate

NOx Rate (lb/hr) 1227 982 320 982 320

NOx Rate (lb/MMBtu) 0.19 0.15 0.05 0.15 0.05

NOx (TPY) 4495 3596 1170 3,596 1,170

Tons/Year Removed 1556 899 3324 2,455 4,880

Total Cost/year $2,268,806 $6,286,091 $15,902,235 $8,554,896 $18,171,041

$/Ton $1,458 $6,993 $4,784 $3,485 $3,723

Incremental $/ton $3,965 $6,993 $3,965

LR2

Comb Control (CC) SNCR SCR CC and SNCR CC and SCR

Capital Cost, $/kW $37 $30 $294 $67 $331

Control Efficiency 29% 20% 74% 43% 82%

Uncontrolled Rate

NOx Rate (lb/hr) 1688 1199 1199 1688 1688

NOx Rate (lb/MMBtu) 0.27 0.19 0.19 0.27 0.27

NOx (TPY) 6293 4470 4470 6,293 6,293

Controlled Rate

NOx Rate (lb/hr) 1199 959 312 959 312

NOx Rate (lb/MMBtu) 0.19 0.15 0.05 0.15 0.05

NOx (TPY) 4470 3576 1164 3,576 1,164

Tons/Year Removed 1823 894 3306 2,717 5,129

Total Cost/year $2,268,806 $6,262,825 $18,191,651 $8,531,631 $20,460,457

$/Ton $1,244 $7,006 $5,503 $3,140 $3,989

Incremental $/ton $4,946 $7,006 $4,946

LR 3

Comb Control (CC) SNCR SCR CC and SNCR CC and SCR

Capital Cost, $/kW $37 $30 $294 $67 $331

Control Efficiency 28% 20% 74% 42% 81%

Uncontrolled Rate

NOx Rate (lb/hr) 1778 1279 1279 1778 1778

NOx Rate (lb/MMBtu) 0.27 0.19 0.19 0.27 0.27

NOx (TPY) 6375 4586 4586 6,375 6,375

Controlled Rate

NOx Rate (lb/hr) 1279 1023 333 1023 333

NOx Rate (lb/MMBtu) 0.19 0.15 0.05 0.15 0.05

NOx (TPY) 4586 3669 1194 3,669 1,194

Tons/Year Removed 1789 917 3392 2,706 5,181

Total Cost/year $2,268,806 $6,375,033 $16,416,942 $8,643,839 $18,685,748

$/Ton $1,268 $6,951 $4,840 $3,194 $3,607

Incremental $/ton $4,058 $6,951 $4,058
LR 1

Comb Control (CC) SNCR SCR CC and SNCR CC and SCR

Capital Cost, $/kW $37 $30 $282 $67 $319

Control Efficiency 26% 20% 74% 41% 81%

Uncontrolled Rate

NOx Rate (lb/hr) 1652 1227 1227 1652 1652

NOx Rate (lb/MMBtu) 0.26 0.19 0.19 0.26 0.26

NOx (TPY) 6051 4495 4495 6,051 6,051

Controlled Rate

NOx Rate (lb/hr) 1227 982 320 982 320

NOx Rate (lb/MMBtu) 0.19 0.15 0.05 0.15 0.05

NOx (TPY) 4495 3596 1170 3,596 1,170

Tons/Year Removed 1556 899 3324 2,455 4,880

Total Cost/year $2,268,806 $6,286,091 $19,501,329 $8,554,896 $21,770,134

$/Ton $1,458 $6,993 $5,866 $3,485 $4,461

Incremental $/ton $5,449 $6,993 $5,449

LR2

Comb Control (CC) SNCR SCR CC and SNCR CC and SCR

Capital Cost, $/kW $37 $30 $294 $67 $331

Control Efficiency 29% 20% 74% 43% 82%

Uncontrolled Rate

NOx Rate (lb/hr) 1688 1199 1199 1688 1688

NOx Rate (lb/MMBtu) 0.27 0.19 0.19 0.27 0.27

NOx (TPY) 6293 4470 4470 6,293 6,293

Controlled Rate

NOx Rate (lb/hr) 1199 959 312 959 312

NOx Rate (lb/MMBtu) 0.19 0.15 0.05 0.15 0.05

NOx (TPY) 4470 3576 1164 3,576 1,164

Tons/Year Removed 1823 894 3306 2,717 5,129

Total Cost/year $2,268,806 $6,262,825 $20,422,662 $8,531,631 $22,691,467

$/Ton $1,244 $7,006 $6,178 $3,140 $4,424

Incremental $/ton $5,871 $7,006 $5,871

LR 3

Comb Control (CC) SNCR SCR CC and SNCR CC and SCR

Capital Cost, $/kW $37 $30 $294 $67 $331

Control Efficiency 28% 20% 74% 42% 81%

Uncontrolled Rate

NOx Rate (lb/hr) 1778 1279 1279 1778 1778

NOx Rate (lb/MMBtu) 0.27 0.19 0.19 0.27 0.27

NOx (TPY) 6375 4586 4586 6,375 6,375

Controlled Rate

NOx Rate (lb/hr) 1279 1023 333 1023 333

NOx Rate (lb/MMBtu) 0.19 0.15 0.05 0.15 0.05

NOx (TPY) 4586 3669 1194 3,669 1,194

Tons/Year Removed 1789 917 3392 2,706 5,181

Total Cost/year $2,268,806 $6,375,033 $20,398,176 $8,643,839 $22,666,982

$/Ton $1,268 $6,951 $6,014 $3,194 $4,375

Incremental $/ton $5,667 $6,951 $5,667
N1

Comb Control (CC) SNCR SCR CC and SNCR CC and SCR

Capital Cost, $/kW $55 $20 $362 $75 $416

Control Efficiency 59% 25% 76% 69% 90%

Uncontrolled Rate

NOx Rate (lb/hr) 895 366 366 895 895

NOx Rate (lb/MMBtu) 0.52 0.21 0.21 0.52 0.52

NOx (TPY) 3553 1453 1453 3553 3553

Controlled Rate

NOx Rate (lb/hr) 366 274 87 274 87

NOx Rate (lb/MMBtu) 0.21 0.16 0.05 0.16 0.05

NOx (TPY) 1453 1090 345 1090 345

Tons/Year Removed 2100 363 1109 2463 3209

Total Cost/year $932,466 $1,302,361 $7,254,468 $2,234,827 $8,186,934

$/Ton $444 $3,584 $6,543 $907 $2,551

Incremental Rate $7,985 $3,584 $7,985

N 2

Comb Control (CC) SNCR SCR CC and SNCR CC and SCR

Capital Cost, $/kW $40 $20 $343 $60 $382

Control Efficiency 60% 25% 76% 70% 90%

Uncontrolled Rate

NOx Rate (lb/hr) 1174 474 474 1174 1174

NOx Rate (lb/MMBtu) 0.52 0.21 0.21 0.52 0.52

NOx (TPY) 4337 1752 1752 4337 4337

Controlled Rate

NOx Rate (lb/hr) 474 356 112 356 112

NOx Rate (lb/MMBtu) 0.21 0.16 0.05 0.16 0.05

NOx (TPY) 1752 1314 415 1314 415

Tons/Year Removed 2586 438 1336 3024 3922

Total Cost/year $883,900 $1,596,932 $8,937,135 $2,480,832 $9,821,035

$/Ton $342 $3,647 $6,688 $820 $2,504

Incremental Rate $8,171 $3,647 $8,171

N 3

Comb Control (CC) SNCR SCR CC and SNCR CC and SCR

Capital Cost, $/kW $3 $20 $322 $23 $325

Control Efficiency 10% 30% 85% 37% 86%

Uncontrolled Rate

NOx Rate (lb/hr) 1266 1142 1142 1266 1266

NOx Rate (lb/MMBtu) 0.37 0.33 0.33 0.37 0.37

NOx (TPY) 4544 4101 4101 4544 4544

Controlled Rate

NOx Rate (lb/hr) 800 173 800 173

NOx Rate (lb/MMBtu) 0.33 0.23 0.05 0.23 0.05

NOx (TPY) 4101 2871 621 2871 621

Tons/Year Removed 442 1230 3480 1673 3922

Total Cost/year $106,393 $3,745,984 $13,498,309 $3,852,377 $13,604,702

$/Ton $240 $3,045 $3,879 $2,303 $3,469

Incremental Rate $4,335 $3,045 $4,335
N1

Comb Control (CC) SNCR SCR CC and SNCR CC and SCR

Capital Cost, $/kW $55 $20 $467 $75 $521

Control Efficiency 59% 25% 76% 69% 90%

Uncontrolled Rate

NOx Rate (lb/hr) 895 366 366 895 895

NOx Rate (lb/MMBtu) 0.52 0.21 0.21 0.52 0.52

NOx (TPY) 3553 1453 1453 3553 3553

Controlled Rate

NOx Rate (lb/hr) 366 274 87 274 87

NOx Rate (lb/MMBtu) 0.21 0.16 0.05 0.16 0.05

NOx (TPY) 1453 1090 345 1090 345

Tons/Year Removed 2100 363 1109 2463 3209

Total Cost/year $932,466 $1,302,361 $9,042,150 $2,234,827 $9,974,616

$/Ton $444 $3,584 $8,155 $907 $3,109

Incremental Rate $10,384 $3,584 $10,384

N 2

Comb Control (CC) SNCR SCR CC and SNCR CC and SCR

Capital Cost, $/kW $40 $20 $353 $60 $393

Control Efficiency 60% 25% 76% 70% 90%

Uncontrolled Rate

NOx Rate (lb/hr) 1174 474 474 1174 1174

NOx Rate (lb/MMBtu) 0.52 0.21 0.21 0.52 0.52

NOx (TPY) 4337 1752 1752 4337 4337

Controlled Rate

NOx Rate (lb/hr) 474 356 112 356 112

NOx Rate (lb/MMBtu) 0.21 0.16 0.05 0.16 0.05

NOx (TPY) 1752 1314 415 1314 415

Tons/Year Removed 2586 438 1336 3024 3922

Total Cost/year $883,900 $1,596,932 $9,178,850 $2,480,832 $10,062,750

$/Ton $342 $3,647 $6,869 $820 $2,566

Incremental Rate $8,440 $3,647 $8,440

N 3

Comb Control (CC) SNCR SCR CC and SNCR CC and SCR

Capital Cost, $/kW $3 $20 $322 $23 $325

Control Efficiency 10% 30% 85% 37% 86%

Uncontrolled Rate

NOx Rate (lb/hr) 1266 1142 1142 1266 1266

NOx Rate (lb/MMBtu) 0.37 0.33 0.33 0.37 0.37

NOx (TPY) 4544 4101 4101 4544 4544

Controlled Rate

NOx Rate (lb/hr) 800 173 800 173

NOx Rate (lb/MMBtu) 0.33 0.23 0.05 0.23 0.05

NOx (TPY) 4101 2871 621 2871 621

Tons/Year Removed 442 1230 3480 1673 3922

Total Cost/year $106,393 $3,745,984 $13,498,309 $3,852,377 $13,604,702

$/Ton $240 $3,045 $3,879 $2,303 $3,469

Incremental Rate $4,335 $3,045 $4,335
N1

Comb Control (CC) SNCR SCR CC and SNCR CC and SCR

Capital Cost, $/kW $55 $20 $362 $75 $416

Control Efficiency 59% 25% 76% 69% 90%

Uncontrolled Rate

NOx Rate (lb/hr) 895 366 366 895 895

NOx Rate (lb/MMBtu) 0.52 0.21 0.21 0.52 0.52

NOx (TPY) 3553 1453 1453 3553 3553

Controlled Rate

NOx Rate (lb/hr) 366 274 87 274 87

NOx Rate (lb/MMBtu) 0.21 0.16 0.05 0.16 0.05

NOx (TPY) 1453 1090 345 1090 345

Tons/Year Removed 2100 363 1109 2463 3209

Total Cost/year $1,002,863 $1,427,046 $11,950,751 $2,429,910 $12,953,615

$/Ton $478 $3,927 $10,779 $986 $4,037

Incremental Rate $14,118 $3,927 $14,118

N 2

Comb Control (CC) SNCR SCR CC and SNCR CC and SCR

Capital Cost, $/kW $40 $20 $343 $60 $382

Control Efficiency 60% 25% 76% 70% 90%

Uncontrolled Rate

NOx Rate (lb/hr) 1174 474 474 1174 1174

NOx Rate (lb/MMBtu) 0.52 0.21 0.21 0.52 0.52

NOx (TPY) 4337 1752 1752 4337 4337

Controlled Rate

NOx Rate (lb/hr) 474 356 112 356 112

NOx Rate (lb/MMBtu) 0.21 0.16 0.05 0.16 0.05

NOx (TPY) 1752 1314 415 1314 415

Tons/Year Removed 2586 438 1336 3024 3922

Total Cost/year $950,631 $1,760,581 $12,069,960 $2,711,212 $13,020,591

$/Ton $368 $4,020 $9,033 $897 $3,320

Incremental Rate $11,476 $4,020 $11,476
W 1

Comb Control (CC) SNCR SCR CC and SNCR CC and SCR

Capital Cost, $/kW $36 $20 $321 $56 $357

Control Efficiency 27% 20% 74% 41% 81%

Uncontrolled Rate

NOx Rate (lb/hr) 1060 775 775 1060 1060

NOx Rate (lb/MMBtu) 0.26 0.19 0.19 0.26 0.26

NOx (TPY) 4615 3376 3376 4,615 4,615

Controlled Rate

NOx Rate (lb/hr) 775 620 202 620 202

NOx Rate (lb/MMBtu) 0.19 0.15 0.05 0.15 0.05

NOx (TPY) 3376 2701 880 2,701 880

Tons/Year Removed 1239 675 2496 1,914 3,735

Total Cost/year $1,272,427 $2,454,146 $13,801,075 $3,726,573 $15,073,502

$/Ton $1,027 $3,635 $5,530 $1,947 $4,036

Incremental Rate $6,233 $3,635 $6,233
Chemical Engineering Plant Cost Index (CEPCI)

Year Index CEPCI % growth from 2000

2000 394.1 0 218.2973

2001 394.3 0.05%

2002 395.6 0.38%

2003 402.0 2.00%

2004 444.2 12.71%

2005 468.2 18.80%

2006 499.6 26.77%

2007 525.4 33.32%

2008 575.4 46.00%

2009 521.9 32.43%

2010 550.8 39.76%

2011 593.2 50.52%

2012 582.2 47.73%

2013 564.9 43.34%

-4.28%

0%

10%

20%

30%

40%

50%

60%

300

350

400

450

500

550

600

2000200120022003200420052006200720082009201020112012

Percent change in CEPCI since 2000

CEPCI

Year

Chemical Engineering Plant

Cost Index (CEPCI)

CEPCI % growth from 2000
Plant Unit SCR cost In service

Capacity 

(net MW) $/kW

$/kW 

(2013)

1 $30,500,000 2003 245 $124 $175

2 $28,800,000 2002 245 $118 $168

3 $50,000,000 2002 245 $204 $291

Bull Run 1 $210,000,000 2004 881 $238 $303

Colbert 5 $102,000,000 2003 459 $222 $312

1 $165,000,000 2003 1232 $134 $188

2 $159,000,000 2004 1233 $129 $164

1 $25,250,000 2004 134 $188 $240

2 $25,250,000 2004 134 $188 $240

3 $25,250,000 2004 134 $188 $240

4 $25,250,000 2004 134 $188 $240

5 $28,000,000 2005 175 $160 $193

6 $28,000,000 2005 175 $160 $193

7 $28,000,000 2004 175 $160 $203

8 $28,000,000 2004 175 $160 $203

9 $21,000,000 2006 175 $120 $136

1 $44,000,000 2001 616 $71 $102

2 $59,000,000 2000 602 $98 $140

3 $124,500,000 2003 977 $127 $179

7 $65,900,000 2003 473 $139 $196

8 $61,000,000 2004 464 $131 $167

Average $155 $204

Median $160 $193

Minimum $71 $102

Maximum $238 $312

SCR Cost from Defendant's Response to Plaintiff's Interrogatory #8

North Carolina v. TVA, Filed with US District Court

Asheville, NC, September 1, 2006.

30

Allen

Cumberland

Kingston

Paradise

Widows Creek
NEEDS v4.10

Plant Name UniqueID_Final ORIS Plant Code Boiler/Generator/Committed Unit Unit ID CAMD Database UnitID Unique ID PlantType Combustion Turbine/IC 

Allen Steam Plant 3393_B_1 3393 B 1 2248 3393_1 Coal Steam

Allen Steam Plant 3393_B_2 3393 B 2 2249 3393_2 Coal Steam

Allen Steam Plant 3393_B_3 3393 B 3 2250 3393_3 Coal Steam

Bull Run 3396_B_1 3396 B 1 2251 3396_1 Coal Steam

Colbert 47_B_1 47 B 1 35 47_1 Coal Steam

Colbert 47_B_2 47 B 2 36 47_2 Coal Steam

Colbert 47_B_3 47 B 3 37 47_3 Coal Steam

Colbert 47_B_4 47 B 4 38 47_4 Coal Steam

Colbert 47_B_5 47 B 5 39 47_5 Coal Steam

Cumberland 3399_B_1 3399 B 1 2252 3399_1 Coal Steam

Cumberland 3399_B_2 3399 B 2 2253 3399_2 Coal Steam

Kingston 3407_B_1 3407 B 1 2280 3407_1 Coal Steam

Kingston 3407_B_2 3407 B 2 2281 3407_2 Coal Steam

Kingston 3407_B_3 3407 B 3 2282 3407_3 Coal Steam

Kingston 3407_B_4 3407 B 4 2283 3407_4 Coal Steam

Kingston 3407_B_5 3407 B 5 2284 3407_5 Coal Steam

Kingston 3407_B_6 3407 B 6 2285 3407_6 Coal Steam

Kingston 3407_B_7 3407 B 7 2286 3407_7 Coal Steam

Kingston 3407_B_8 3407 B 8 2287 3407_8 Coal Steam

Kingston 3407_B_9 3407 B 9 2288 3407_9 Coal Steam

Paradise 1378_B_1 1378 B 1 913 1378_1 Coal Steam

Paradise 1378_B_2 1378 B 2 914 1378_2 Coal Steam

Paradise 1378_B_3 1378 B 3 915 1378_3 Coal Steam

Widows Creek 50_B_1 50 B 1 40 50_1 Coal Steam

Widows Creek 50_B_2 50 B 2 41 50_2 Coal Steam

Widows Creek 50_B_3 50 B 3 42 50_3 Coal Steam

Widows Creek 50_B_4 50 B 4 43 50_4 Coal Steam

Widows Creek 50_B_5 50 B 5 44 50_5 Coal Steam

Widows Creek 50_B_6 50 B 6 45 50_6 Coal Steam

Widows Creek 50_B_7 50 B 7 46 50_7 Coal Steam

Widows Creek 50_B_8 50 B 8 47 50_8 Coal Steam
Region NameState NameState Code County County CodeFIPS5 Capacity (MW)

TVA Tennessee 47 Shelby 157 47157 245

TVA Tennessee 47 Shelby 157 47157 245

TVA Tennessee 47 Shelby 157 47157 245

TVA Tennessee 47 Anderson 1 47001 881

TVA Alabama 1 Colbert 33 01033 177

TVA Alabama 1 Colbert 33 01033 177

TVA Alabama 1 Colbert 33 01033 177

TVA Alabama 1 Colbert 33 01033 173

TVA Alabama 1 Colbert 33 01033 459

TVA Tennessee 47 Stewart 161 47161 1232

TVA Tennessee 47 Stewart 161 47161 1233

TVA Tennessee 47 Roane 145 47145 134

TVA Tennessee 47 Roane 145 47145 134

TVA Tennessee 47 Roane 145 47145 134

TVA Tennessee 47 Roane 145 47145 134

TVA Tennessee 47 Roane 145 47145 175

TVA Tennessee 47 Roane 145 47145 175

TVA Tennessee 47 Roane 145 47145 175

TVA Tennessee 47 Roane 145 47145 175

TVA Tennessee 47 Roane 145 47145 175

TVA Kentucky 21 Muhlenberg 177 21177 616

TVA Kentucky 21 Muhlenberg 177 21177 602

TVA Kentucky 21 Muhlenberg 177 21177 977

TVA Alabama 1 Jackson 71 01071 111

TVA Alabama 1 Jackson 71 01071 111

TVA Alabama 1 Jackson 71 01071 111

TVA Alabama 1 Jackson 71 01071 111

TVA Alabama 1 Jackson 71 01071 111

TVA Alabama 1 Jackson 71 01071 111

TVA Alabama 1 Jackson 71 01071 473

TVA Alabama 1 Jackson 71 01071 464