### OP_YEAR STATE FACILITY_NAME ORISPL_CODE UNITID OP_STATUS_INFO

UNIT_TYPE_INFO PRIMARY_FUEL_INFO
2000 ND Milton R Young 2823 B2 Operating Cyclone boiler Coal
2001 ND Milton R Young 2823 B2 Operating Cyclone boiler Coal
2002 ND Milton R Young 2823 B2 Operating Cyclone boiler Coal
2003 ND Milton R Young 2823 B2 Operating Cyclone boiler Coal
2004 ND Milton R Young 2823 B2 Operating Cyclone boiler Coal
2005 ND Milton R Young 2823 B2 Operating Cyclone boiler Coal
2006 ND Milton R Young 2823 B2 Operating Cyclone boiler Coal
2007 ND Milton R Young 2823 B2 Operating Cyclone boiler Coal
2008 ND Milton R Young 2823 B2 Operating Cyclone boiler Coal
2009 ND Milton R Young 2823 B2 Operating Cyclone boiler Coal
2010 ND Milton R Young 2823 B2 Operating Cyclone boiler Coal
2011 ND Milton R Young 2823 B2 Operating Cyclone boiler Coal

### SECONDARY_FUEL_INFO

SO2_CONTROL_INFO Dual Alkali Dual Alkali Dual Alkali Dual Alkali Dual Alkali Dual Alkali Dual Alkali Dual Alkali Dual Alkali Dual Alkali Dual Alkali Wet Lime FGD (Began Oct 01, 2010) Dual Alkali Wet Lime FGD

### NOX_CONTROL_INFO

Overfire Air (Began Nov 26, 2007) Overfire Air Overfire Air Overfire Air Selective Non-catalytic Reduction (Began Dec 08, 2010) Overfire Air Selective Non-catalytic Reduction

### PART_CONTROL_INFO

Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator**CAMD Emissions Data**

STATE FACILITY NAME ORISPL
CODE UNIT ID OP YEAR SUM OP
TIME NUM

MONTHS
REPORTED SO2 MASS SO2
RATE NOX
RATE NOX

MASS CO2 MASS HEAT INPUT (mmBtu/yr) HEAT INPUT

(mmBtu/hr)
ND Milton R Young 2823 Unit B1 2000 7,530 12 18,095 1.914 0.801 7,656 2,055,328 18,912,797 2,512
ND Milton R Young 2823 B1 2001 8,461 12 23,179 1.999 0.784 9,132 2,524,491 23,194,117 2,741
ND Milton R Young 2823 B1 2002 8,304 12 19,858 1.853 0.789 8,510 2,333,523 21,434,050 2,581
ND Milton R Young 2823 B1 2003 7,429 12 18,020 1.757 0.815 8,546 2,233,328 20,513,979 2,761
ND Milton R Young 2823 B1 2004 8,529 12 21,586 1.869 0.843 9,785 2,515,207 23,102,856 2,709
ND Milton R Young 2823 B1 2005 8,355 12 19,450 1.932 0.836 8,458 2,192,181 20,135,772 2,410
ND Milton R Young 2823 B1 2006 7,442 12 16,875 1.908 0.802 7,150 1,925,330 17,684,694 2,376
ND Milton R Young 2823 B1 2007 8,413 12 20,543 1.985 0.838 8,704 2,253,967 20,703,216 2,461
ND Milton R Young 2823 B1 2008 8,297 12 19,608 1.946 0.806 8,193 2,193,430 20,146,954 2,428
ND Milton R Young 2823 B1 2009 7,209 12 16,498 1.891 0.749 6,612 1,899,681 17,449,077 2,421
ND Milton R Young 2823 B1 2010 8,533 12 19,287 1.858 0.540 5,604 2,260,697 20,765,112 2,434

Averages 20,367,511 2,530

ND Milton R Young 2823 Unit B2 2000 8,376 12 21,134 0.987 0.839 18,074 4,658,796 42,819,559 5,112
ND Milton R Young 2823 B2 2001 7,029 12 12,377 0.776 0.833 13,450 3,473,094 31,901,487 4,538
ND Milton R Young 2823 B2 2002 8,171 12 8,707 0.495 0.811 14,335 3,832,125 35,199,243 4,308
ND Milton R Young 2823 B2 2003 8,201 12 10,064 0.519 0.775 15,145 4,224,167 38,800,281 4,731
ND Milton R Young 2823 B2 2004 7,262 12 9,795 0.577 0.806 13,815 3,693,403 33,925,045 4,671
ND Milton R Young 2823 B2 2005 8,120 12 9,957 0.548 0.831 15,223 3,955,523 36,332,357 4,474
ND Milton R Young 2823 B2 2006 8,018 12 10,005 0.553 0.808 14,773 3,937,649 36,167,095 4,511
ND Milton R Young 2823 B2 2007 6,403 12 7,660 0.545 0.856 12,170 3,061,241 28,117,747 4,391
ND Milton R Young 2823 B2 2008 8,385 12 9,302 0.496 0.460 8,599 4,081,707 37,491,532 4,472
ND Milton R Young 2823 B2 2009 8,127 12 9,226 0.503 0.405 7,434 3,995,274 36,697,676 4,516
ND Milton R Young 2823 B2 2010 6,345 12 7,813 0.530 0.409 6,001 3,212,523 29,507,936 4,651

Averages 35,178,178 4,580

### 0.500

0.600 0.700 0.800 0.900**N O** **x E** **m i** **s s** **i o** **n s** **( l** **b /** **m m** **B t** **u )**  

# MR Y **oung NOx Emission Rates**

Unit B1

Unit B2

0.000 0.100 0.200 0.300 0.400

2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010**N O** **x E** **m i** **s s** **i o** **n s** **( l** **b /** **m m** **B t** **u )** 



### Year

### 12,000

14,000 16,000 18,000 20,000**N O** **x E** **m i** **s s** **i o** **n s** **( t** **p y** **)** 

# MR Y **oung NOx Mass Emissions**

Unit B1

Unit B2

- 2,000 4,000 6,000 8,000 10,000

2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010**N O** **x E** **m i** **s s** **i o** **n s** **( t** **p y** **)**



### Year**Minnkota Power--Milton R. Young 2** 

**SNCR from OAQPS Control Cost Manual, Section 4.2**

**Given/Assumptions** Rating (MW ) 477 ND DOH SIP Appendix B.4 report Fuel High Heating Value (Btu/lb) 6,662 from table 3-2 in 10/06 BACT analysis Maximum Fuel Consumption Rate (lb/hr) 7.3E+05 calculated from **4,885** mmBtu/hr from "Summary" cell B3 in ERG report Average Annual Fuel Consumption (lb) 6.03E+09 calculated 40,182,251 calculated mmBtu/yr Number of SNCR Operating Days calculated from 8,760 hr/yr assumed Total system capacity factor 93.9% ERG report Uncontrolled NOx Concentration (lb/mmBtu) 0.786 from Table 3-7 in the October 2006 company BACT report NOx concentration after combustion controls 0.489 ND DOH SIP Appendix B.4 report Required Controlled NOx Concentration (lb/mmBtu) 0.330 ND DOH SIP Appendix B.4 report Source/State Total Capital Investmant estimate 7,120,000 $ calculated from Table 3-10 in the October 2006 company BACT report ash product (Btu/mmBtu) 7.7E+04 OAQPS Control Cost Manual Stored Urea Concentration 50% OAQPS Control Cost Manual Injected Urea Concentration 10% OAQPS Control Cost Manual Reagent Heat of vaporization Hv (lb/Btu) 900 OAQPS Control Cost Manual Reagent Molecular W eight (g/mole) 60.06 OAQPS Control Cost Manual SR T 2 OAQPS Control Cost Manual Reagent Density (lb/ft3 @ 60F) 71.0 OAQPS Control Cost Manual Reagent Specific Volume (gal/ft3) 7.481 OAQPS Control Cost Manual NOx Molecular W eight (g/mole) 46.01 OAQPS Control Cost Manual Number of Days of Storage for Urea 14 OAQPS Control Cost Manual Equipment Life (years) 20 OAQPS Control Cost Manual Annual Interest Rate 7% OAQPS Control Cost Manual Inflation Since 1998 1.34 CEPCI 2009/CEPCI 1998 Inflation Since 2006 1.04 CEPCI 2009/CEPCI 2006 Wa ter Consumption Cost ($/gal) 0.0004 OAQPS Control Cost Manual Electrical Power Cost ($/kW h) 0.035 $ calculated from 35.00 $ /MW hr from from Table C.1-1 company 10/06 BACT report 50% Urea Solution Cost ($/gal) 1.80 $ calculated from 380 $ /ton 50% aqueous solution from Table C.1-1 company 10/06 BACT report Coal Cost ($/mmBtu) 0.91 $ from Leland Olds company report Ash Disposal Cost ($/ton) 11.28 $ OAQPS Control Cost Manual

### Boiler Calculations

1.3 Q B 

### = HVm -dot fuel 

### QB = 6662 Btu/lb * 733,263 lb/hr QB = 4885 mmB tu/hr

1.7 CF Plant 

### = actual m fuel 

### /maximum m fuel 

### CFPlant = 6.03E+09 lb/y r / 8760 hr/y r / 733,263 lb/hr CFPlant = 93.9%

1.8 CF SNCR 

### = t SCR 

### /365 day s CFSCR = 0 day s/ 365 day s CFSCR = 0%

1.6 CF Total 

### = CF Plant 

### x CF SNCR 

### CFTotal = 94% * 0% CFTotal = 93.9%

1.9 η NOx 

### = (NOx in 

### – NOx out 

### ) / NOx in 

### ηNOx = ( 0.489 lb/m mB tu - 0.33 lb/m mB tu)/ 0.489 lb/m mB tu ηNOx = 33%

**Uncontrolled NOx emissions (tpy) 15,792** 

### Reagent Calculations 1.14 NSR = [2NOx in 

### – 0.7] η NOx 

### / NOx in 

### NSR = ( 2 * 0.489 + 0.7 ) * 33% / 0.489 NSR = 1.12

1.13 Utilization = η NOx



### /NSR
Utilization = 29%

1.15 m-dot reagent 

### = NOx in 

### Q B 

### η NOx 

### NSR M reagent 

### /M NOx 

### /SR T 

### m-dotreagent = 0.489 * 4885 * 33% * 112% * 60.06 / 2 / 46.01 m-dotreagent = 566 lb/hr

1.16 m-dot sol 

### = m -dot reagent 

### /C sol 

### m-dotsol = 566 / 0.50 m-dotsol = 1131 lb/hr

1.17 q sol 

### = m -dot vol 

### /ρ sol 

### qsol = 1131 * 7.481 / 71 qsol = 119 gph

2.35 Tank Volume = q sol 

### t
Tank Volume = 119 * 14 * 24 Tank Volume = 40,050 gal

### Direct Capital Cost

1.19 DC = ($950/mmBtu/hr) * Q B 

### (mmBtu/hr)[(2375/mmBtu/hr)/Q B 

### (mmBtu/hr] 0.577 

### * (0.66 + 0.85* η NOx 

### ) DC = 950 $ * 4885 *( 2375 / 4885 )^ 0.577 *( 0.66 + 0.85 * 33% ) DC = 2,866,312 $

**Inflation Adjustment =** 1.34

DC = 3,840,859 $

### Indirect Capital Costs

**Total Direct Capital Costs, A** 

### 3,840,859 $ Indirect Installation Costs

General Facilities 0.05 A $192,043 Engineering and Hom e Office Fees 0.10 A $384,086 Process Contingencies 0.05 A $192,043 **Total Indirect Installation Costs, B** 0.20 A $768,172

Project Contingency , C = 0.15 (A+B) $691,355 **Total Plant Cost D =** A+B+C $5,300,385

Preproduction Cost 0.02 D $106,008 Inventory Capital $72,220 **Total Capital Investment TCI = D+G+H** +D+E+F+G+H+I $5,478,613

**Source TCI =** 7,437,806 $**Annual Costs**

2.45 DAC = Annual Maintenance Cost + Annual Reagent Cost + Annual Electricity Cost + Annual Water Cost + Annual Catalyst Cost 2.46 Annual Maintenance Cost = 0.015 TCI Annual Maintenance Cost = 0.015 * 7,437,806 $ Annual Maintenance Cost = 111,567 $
1.22 Annual Reagent Cost = q sol Cost reagent t op 1.22.a t op = CF total 8760hr/yr top = 94% * 8760 top = 8226 Annual Reagent Cost = 119 * 1.803234862 * 8226 Annual Reagent Cost = 1,768,029 $
1.24 Annual Electricity Cost = Power (Cost elect )t op 1.23 Power = 0.47NOx in NSRQ B /9.5
Power = 0.47 * 0.489 * 1.12 * 4885 / 9.5 Power = 132 kW Annual Electricity Cost = 132 * 8226 * 0.035 Annual Electricity Cost = 37,963 $
1.27 Annual Water Cost = q water Cost water t op 1.25 q water

= m-dot sol /ρ water [Curea stored /Curea sol inj -1] qwater = 1131 / 8.345 *( 50% / 10%

- 1 ) qwater = 542 Annual Water Cost = 542 * 0.0004 * 8226 Annual Water Cost = 1,784 $
1.31 Annual ΔCoal cost = ΔCoal cost coal t op 1.28 ΔCoal(Btu/hr) = Hv(Btu/lb)* m-dot reagent (lb/hr)[1/ Curea sol inj -1] ΔCoal(Btu/hr) = 900 * 1131 *( 1 / 10%

- 1 ) ΔCoal(Btu/hr) = 9,163,284 Annual ΔCoal cost = 9.2 * 0.91 $ * 8226 Annual ΔCoal cost = 68,590

$

1.32 Annual ΔAsh cost = ΔAsh cost ash t op 1.30 ΔAsh = ΔCoal ash product/HHV ΔAsh = 9 * 77000 / 6662 ΔAsh = 106 Annual ΔAsh cost = 106 * 11.28 $ * 8226 / 2000 Annual ΔAsh cost = 4,913

$

Total Variable Cost = 1,881,280

$

Total Direct Annual Cost = 111,567 $ + 1,881,280 $ Total Direct Annual Cost = 1,992,847 $

1.34 CRF = i(1+i) n /[(1+i) n -1] CRF = 0.07 *( 1 + 0.07 )^ 20 /(( 1 + 0.07 )^ 20

- 1 ) CRF = 0.0944 1.33 IDAC = CRF*TCI Indirect Annual Cost = 0.0944 * 7,437,806 $ Indirect Annual Cost = 702,076 $

1.35 Total Annual Cost = Direct Annual Cost + Indirect Annual Cost Total Annual Cost = 1,992,847

$ + 702,076 Total Annual Cost = 2,694,923

$

1.36 NOx Removed = NOx in η NOx Q B t op NOx Removed = 0.489 * 33% * 4885 * **8226** / 2000 NOx Removed = 3194

1.37 Cost effectiveness = TAC/NO x removed Cost effectiveness = 844

$

### Milton R. Young Station Unit 2, EPA's SNCR Cost Analysis Summary

**Operating company Minnkota power**  **Facility MR Young**  **State ND**  **Contact Tom Bachman**  **tbachman@nd.gov (701) 328-5188** 

**Proposed Controls proposed A**  **SOFA + SNCR**  Unit 2 Boiler Type cyclone Fuel 

### ND lignite Rating (MW Gross) each 477 ND DOH SIP Appendix B.4 report **Presumptive BA RT limit (lb/mmBtu)**  **0.10 presumptive BA**  **RT for cyclone boiler at facility > 750 MW** Rating (mmBtu/hr) 4,885 ERG report Uncontrolled Emissions (tpy) 15,792 ERG report Uncontrolled Emissions (lb/mmBtu) 0.786 from Table 3-7 in the October 2006 company BACT report

**AS OFA**  **Cost A nalysis**  Control Efficiency 37.8% ND DOH SIP Appendix B.4 report Controlled emissions (lb/mmBtu) 0.489 ND DOH SIP Appendix B.4 report Controlled Emissions (tpy) 9,825 OAQPS Control Cost Manual Emissions Reduction (tpy) 5,967 calculated Capital Cost 10,008,000 $ Table 3-10 in the October 2006 company BACT report Capital Cost ($/kW ) 21 $ Table 3-9 in the October 2006 company BACT report O&M Cost 2,805,000 $ Table 3-11 in the October 2006 company BACT report Annualized Cost 3,749,684 $ calculated from Tables 3-10 thru 3-12 in the October 2006 company BACT report Cost-Effectiveness ($/ton) 628 $ calculated

**SNCR Cost A nalysis**  Control Efficiency 33% OAQPS Control Cost Manual Controlled emissions (lb/mmBtu) 0.330 ND DOH SIP Appendix B.4 report Controlled Emissions (tpy) 6,630 calculated Emissions Reduction (tpy) 3,194 OAQPS Control Cost Manual Capital Cost 7,437,806 $ calculated form company estimate Capital Cost ($/kW ) 16 $ calculated form company estimate O&M Cost 1,992,847 $ hybrid Annualized Cost 2,694,923 $ hybrid Cost-Effectiveness ($/ton) 844 $ hybrid

**AS OFA**  **+SNCR Cost A nalysis**  Control Efficiency 58% calculated Controlled emissions (lb/mmBtu) 0.330 ND DOH SIP Appendix B.4 report Controlled Emissions (tpy) 6,630 calculated Emissions Reduction (tpy) 9,162 calculated Capital Cost 17,445,806 $ calculated Capital Cost ($/kW ) 37 $ calculated O&M Cost 4,797,847 $ calculated Annualized Cost 6,444,608 $ calculated Cost-Effectiveness ($/ton) 703 $ calculated