# 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

# This has the calculations for combustion controls based upon a post combustion control emissions and 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 4158BW41 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 4158BW42 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 4158BW43 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 4158BW44 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 6101BW91 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 210user 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+09A*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 60.00Total 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 $950,631TPC*CR+(FOM*MW)+VOM(MW*8760)*CF **$/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 6002000200120022003200420052006200720082009201020112012**P e** **r c** **e n** **t c** **h a** **n g** **e i** **n C** **E P** **C I** **s i** **n c** **e 2** **0 0** **0 C** **E P** **C I** 



# 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 Engine Allen Steam Plant 3393_B_1 3393B 1 22483393_1 Coal Steam Allen Steam Plant 3393_B_2 3393B 2 22493393_2 Coal Steam Allen Steam Plant 3393_B_3 3393B 3 22503393_3 Coal Steam Bull Run 3396_B_1 3396B 1 22513396_1 Coal Steam Colbert 47_B_1 47B 1 3547_1 Coal Steam Colbert 47_B_2 47B 2 3647_2 Coal Steam Colbert 47_B_3 47B 3 3747_3 Coal Steam Colbert 47_B_4 47B 4 3847_4 Coal Steam Colbert 47_B_5 47B 5 3947_5 Coal Steam Cumberland 3399_B_1 3399B 1 22523399_1 Coal Steam Cumberland 3399_B_2 3399B 2 22533399_2 Coal Steam Kingston 3407_B_1 3407B 1 22803407_1 Coal Steam Kingston 3407_B_2 3407B 2 22813407_2 Coal Steam Kingston 3407_B_3 3407B 3 22823407_3 Coal Steam Kingston 3407_B_4 3407B 4 22833407_4 Coal Steam Kingston 3407_B_5 3407B 5 22843407_5 Coal Steam Kingston 3407_B_6 3407B 6 22853407_6 Coal Steam Kingston 3407_B_7 3407B 7 22863407_7 Coal Steam Kingston 3407_B_8 3407B 8 22873407_8 Coal Steam Kingston 3407_B_9 3407B 9 22883407_9 Coal Steam Paradise 1378_B_1 1378B 1 9131378_1 Coal Steam Paradise 1378_B_2 1378B 2 9141378_2 Coal Steam Paradise 1378_B_3 1378B 3 9151378_3 Coal Steam Widows Creek 50_B_1 50B 1 4050_1 Coal Steam Widows Creek 50_B_2 50B 2 4150_2 Coal Steam Widows Creek 50_B_3 50B 3 4250_3 Coal Steam Widows Creek 50_B_4 50B 4 4350_4 Coal Steam Widows Creek 50_B_5 50B 5 4450_5 Coal Steam Widows Creek 50_B_6 50B 6 4550_6 Coal Steam Widows Creek 50_B_7 50B 7 4650_7 Coal Steam Widows Creek 50_B_8 50B 8 4750_8 Coal Steam

# Region Name

State Name

State CodeCounty County Code FIPS5 Capacity (MW) TVA Tennessee 47Shelby 15747157 245 TVA Tennessee 47Shelby 15747157 245 TVA Tennessee 47Shelby 15747157 245 TVA Tennessee 47Anderson 147001 881 TVA Alabama 1Colbert 3301033 177 TVA Alabama 1Colbert 3301033 177 TVA Alabama 1Colbert 3301033 177 TVA Alabama 1Colbert 3301033 173 TVA Alabama 1Colbert 3301033 459 TVA Tennessee 47Stewart 16147161 1232 TVA Tennessee 47Stewart 16147161 1233 TVA Tennessee 47Roane 14547145 134 TVA Tennessee 47Roane 14547145 134 TVA Tennessee 47Roane 14547145 134 TVA Tennessee 47Roane 14547145 134 TVA Tennessee 47Roane 14547145 175 TVA Tennessee 47Roane 14547145 175 TVA Tennessee 47Roane 14547145 175 TVA Tennessee 47Roane 14547145 175 TVA Tennessee 47Roane 14547145 175 TVA Kentucky 21Muhlenberg 17721177 616 TVA Kentucky 21Muhlenberg 17721177 602 TVA Kentucky 21Muhlenberg 17721177 977 TVA Alabama 1Jackson 7101071 111 TVA Alabama 1Jackson 7101071 111 TVA Alabama 1Jackson 7101071 111 TVA Alabama 1Jackson 7101071 111 TVA Alabama 1Jackson 7101071 111 TVA Alabama 1Jackson 7101071 111 TVA Alabama 1Jackson 7101071 473 TVA Alabama 1Jackson 7101071 464