# Results of the December 21-22, 2005 Nitrogen Oxides Engineering Tests on the Furnace Line 11 Waste Gas Stack (SV104) and Furnace Line 6 Hood Exhaust/Waste Gas Stack (SV261) at the Northsh ore Mining Facility Located in Silver Bay, Minnesota
MPCA AQD File No. 27A MPCA Air Permit No. 07500003-002
Barr Project No. 23/38-124 MTP

Prepared for Northshore Mining Company Silver Bay, Minnesota

February 2006

4700 West 77th Street Minneapolis, MN 55435 Phone: (952) 832-2600 Fax: (952) 832-2601 

# BARR

# Northshore Mining Company Silver Bay, Minnesota Stack Test Report

Table of Contents



### Report Certification 1 Executive Summary 3 Introduction 4 Sununary of Results 5 Process Description 6 Sampling and Analysis Procedures 7

Tables Figures Appendices

List of Tables 

### Table 1 Furnace 11 Waste Gas Stack (SV104) — Reference Method Analyzer Results Summary Table 2 Furnace 6 Hood Exhaust/Waste Gas Stack (SV261) — Reference Method Analyzer Results Summary

Figure 1 Figure 2 Figure 3 Figure 4 List of Figures 

### Test Port Location — Furnace 11 (SV104) Traverse Point Locations — Furnace 11 (SV104) Test Port Location — Furnace 6 (SV261) Traverse Point Locations — Furnace 6 (SV261)

List of Appendices 

### Report Calculations and Nomenclature Field Data Sheets Instrument Output Calibration Data Cylinder Gas Certifications Process Operating Data Stack Test Plan Project Participants Appendix A Appendix B Appendix C Appendix D Appendix E Appendix F Appendix G Appendix H

### Signature: 

# Report Certification

Certification of Sampling Procedures: 

### I certify under penalty of law that the sampling procedures were performed in accordance with the approved test plan and that the data presented in this test report are, to the best of my knowledge and belief, true, accurate, and complete. All exceptions are listed and explained below.

Signature: Pet ossmiller Date Sr. Air Quality Technician Barr Engineering Co.

Certification of Analytical Procedures: 

### I certify under penalty of law that the analytical procedures were performed in accordance with the requirements of the test methods and that the data presented for use in the test report were, to the best of my knowledge and belief, true, accurate, and complete. All exceptions are listed and explained below.

Pete Ros 'ller Sr. Air duality Technician Barr Engineering Co. 

# Z/

Date Signature:

Certification of Test Report by Testing Company: 

### I certify under penalty of law that this test report and all attachments were prepared under my direction or supervision in accordance with a system designed to assure that qualified personnel properly gathered and evaluated the test information submitted. Based on my inquiry of the person or persons who performed sampling and analysis relating to the performance test, the information submitted in this test report is, to the best of my knowledge and belief, true, accurate, and complete. All exceptions are listed and explained below.

Pete Rosiller Date Sr. Air Quality Technician Barr Engineering Co.

1

### Certification of Test Report by Owner or Operator of Emission Facility:
I certify under penult) of law that the in submitted in this test report aecuratel) reflects the operating conditions at the emission fad lity during this perl'ormance test and describes the date and nature of all operational and maimenanee activities that were performed on the process and control equipment during the month prior to the performance test. Based on my inquiry of the person or persons who performed the operational and maintenance activities, the in submitted in this test report is. to the best of my km»dedge and belief, true. accurate, and complete. All exceptions are listed and explained bet ass .

Signature: 

# 6

Scott Gischia Date Environmental Engineer Northshore Mining Company

# Executive Surririr rj

Barr Engineering Co. performed nitrogen oxides engineering emissions testing on the Furnace 11 Waste Gas Stack (SV104) and the Furnace 6 Hood Exhaust/Waste Gas Stack (SV261) at Northshore Mining's Facility in Silver Bay, Minnesota. The Furnace 11 Waste Gas stack test was conducted on December 21, 2005. The Furnace 6 Waste Gas/Hood Exhaust stack test was conducted on December 22, 2005. Each emission test included the measurement of nitrogen oxides (N0 x ) concentration and mass emission rate. A summary of the test results (three run averages) are provided in the following table.

Test Parameter Furnace 11 Waste Gas

(SV104) Furnace 6 Waste Gas/Hood Exhaust (SV26I)
Test Date 12/21/05 12/22/05 Stack Temperature, ° F 131 120 Moisture Content, % vol 15.6 15.3 Gas Composition, % vol Oxygen Carbon Dioxide 17.2 1.7 19.1 0.8
Volumetric Air Flow Rate ACFM SCFM DSCFM 79,100 69,500 58,600 68,700 60,300 51,100
Gaseous Pollutant Concentrations NO x , PPMV dry (bias corrected) 101.3 25.8
Gaseous Pollutant Emission Rates NO x , lb/hr NOx, lb/MMBTU 42.6 0.33 9.4 0.14 Fired Pellet Production Rate, LTPH 251 103 Furnace Heat Input, MMBtu/hr 129 68



### 3

# Introduction

Barr Engineering Co. performed nitrogen oxides engineering emission tests on the Furnace 11 Waste Gas stack (SV104) and the Furnace 6 Waste Gas/Hood Exhaust stack (SV261) at the Northshore Mining Company located in Silver Bay, Minnesota. The tests were conducted on December 21-22, 2005. The purpose of testing was to develop current nitrogen dioxide emission factors. The pelletizing furnaces were fired on natural gas during the performance
tests. Each test consisted of three 60-minute test runs.

A test team led by Pete Rossmiller of Barr Engineering conducted the emission tests. Scott Gischia of Northshore Mining provided the coordination of the Barr test team with facility operations. A list of project participants is provided in Appendix H.

Andrew Place, of the Minnesota Pollution Control Agency (MPCA), approved the stack test plan in both a conference call and correspondence dated December 15, 2005. A copy of the stack test plan and the MPCA approval is located in Appendix G. A representative of the MPCA did not witness the performance tests.

Test results are presented in the following section. Field data along with supporting documentation is located in the appendices.

4

# Summ:ry of Re Its

Table 1 summarizes the NOx emissions test results for the Furnace 11 Waste Gas stack (SV104). The nitrogen oxides emission rate averaged 42.6 pounds per hour (lb/hr) at an average dry concentration of 101.3 parts per million by volume (PPMV). Heat input to Furnace 11 averaged 129 million British thermal units per hour (MMBTU/hr) during the test, resulting in a NOx emission factor, as a function of heat input, of 0.33 lb/MMBTU. The fired pellet production rate during the Furnace 11 Waste Gas stack test averaged 251 long tons per hour (LTPH), Average airflow rates in dry standard cubic feet per minute (DSCFM) for Furnace 11 stacks were 58,600 DSCFM for (SV104) and 60,900 DSCFM for (SV105).

Table 2 summarizes the NOx emissions test results for the Furnace 6 Waste Gas/Hood Exhaust stack (SV261), The nitrogen oxides emission rate averaged 9.4 lb/hr at an average dry concentration of 25.8 PPMV. The heat input to Furnace 6 averaged 68 MMBTU/hr during the test, resulting in a NOx emission factor, as a function of heat input, of 0.14 lb/MMBTU. The fired pellet production rate during the Furnace 6 Hood Exhaust stack test averaged 103 LTPH. Average airflow rates for Furnace 6 stacks were 51,100 DSCFM for (SV261); 50,700 DSCFM for (SV262); and 56,000 DSCFM for (SV263).

5

# Proces Dercription

Northshore Mining Company pelletizer's are straight-grate furnaces manufactured by Arthur G. McKee Company. The furnaces have three major operating zones, referred to as the drying zone, firing zone, and the cooling/recoup

zone.

Unfired green balls comprised of iron concentrate and a composite binder of bentonite and organic binder (starch) enter the furnace at the drying zone. Furnace 11 utilizes a layer of previously fired pellets, which are placed on the grate (hearth layer) and the green balls are then placed on the hearth layer at the furnace entrance. The green balls are dried using heat recouped from the furnace. The Line 6 furnace does not incorporate the hearth layer in the pellet firing process. The air from the drying zone is directed to the Hood Exhaust.

The dried pellets enter the firing zone where they are heated sufficiently to initiate an exothermic reaction caused by the conversion of magnetite to hematite. Natural gas and oil burners are located in the firing zone to provide heat input. The furnaces were fired on natural gas during the stack tests. The waste gas is exhausted from the firing zone. The fired pellets enter the cooling/recoup zone, where the exothermic reaction of the pellets is completed.

The hood exhaust and waste gas is directed to wet wall electrostatic precipitators (WWESP's) for emissions control. The Furnace 11 waste gas is split evenly between two WWESP's associated with (SV104 and SV105). The combined exhaust of the Furnace 6 waste gas and hood exhaust is divided between three WWESP's associated with (SV261, SV262 and SV263).

Operating parameters of both furnaces recorded during each of their respective test runs are included in Table 1 and Table 2. The furnace operating parameters included fuel usage and fired pellet production rate (LTPH). Process operating data is provided in Appendix F.

6

# Lftinpling 

# Lnd Analysis Procedur aL

Testing was performed from ports meeting EPA Method 1 (40 CFR Part 60, Appendix A) criteria. A 16-point traverse was performed at the test port location for each stack. Sample port locations and traverse point detail are provided in Figures 1-4.

Volumetric airflow determinations were performed in accordance with EPA Method 2 (40 CFR Part 60, Appendix A) using an S-type pitot tube. An airflow determination was performed in conjunction with each test run on the stacks for which performance testing was completed; Line 11 (SV104) and Line 6 (SV261). One airflow determination was completed on each of the other stacks, Line 11 (SV105) and Line 6 (SV262 and SV263), during Run 1 of the respective tests. An additional airflow determination was performed on Line 6 stack vents (SV262 and SV263) during Run 2 of the Line 6 test.

Stack gas composition and molecular weight was determined by EPA Method 3A (40 CFR Part 60, Appendix A) on Line 11 (SV104) and Line 6 (SV261). Stack gas moisture content was determined following EPA Method 4 (40 CFR Part 60, Appendix A), in conjunction with the EPA Method 7E test.

Nitrogen oxides concentrations were determined in accordance with EPA Method 7E (40 CFR Part 60, Appendix A) on Line 11 (SV104) and Line 6 (SV261).

7

# TablesAverages 97.5 17.1 1.7 101.3 17.2 1.7

79,100 69,500 58,600

42.6

251 129

0.33 

### Northshore Mining Barr Engineering Silver Bay, Minnesota February 1, 2006

Table 1

Line 

### 11 (SV104) - NOx Emission Inventory Testing 

### GASEOUS POLLUTANT TESTING December 21, 2005

Test Date 12/2112005 12/21/2005 12/21/2005 Run Time 0835-0935 1015-1115 1135-1235 NOx System Bias Calibration, ppm,dry Zero Initial 0.1 -0.8 -0.5 Final -0.8 -0.5 2.7 Upscale Calibration Initial 88,9 86.1 86.2 Final 86.1 86.2 89.3 Cal Gas Value 90.5 90.5 90.5 02 System Bias Calibration, %, dry Zero Initial 0.0 0.0 0.1 Final 0.0 0.1 0.1 Upscale Calibration Initial 19.9 19.9 19.9 Final 19.9 19.9 19.9 Cal Gas Value 20.0 20.0 20.0 CO2 System Bias Calibration, %, dry Zero Initial 0.0 0.0 0.0 Final 0.0 0.0 0.0 Upscale Calibration Initial 5.0 5,1 5.0 Final 5.1 5.0 5.0 Cal Gas Value 5.0 5.0 5.0 Measured Concentration Average NOx ppm, dry 98.5 96.5 97.6 Average 02 17.1 17.1 17.1 Average CO2 1.7 1.7 1.7 NOx ppm, dry Bias Corrected 101.8 101.3 100.8 02%, dry 17.2 17.2 17.2 CO 2 %, dry 1.7 1.7 1.7 Volumetric Airflow Rate ACFM 79,114 79,262 79,041 SCFM 69,390 69,572 69,513 DSCFM 58,677 58,503 58,689 Emission Rates NOx, lb/hr 42.8 42.5 42.4 Process Rates Fired pellets 246 253 254 Heat Input MMBtu/hr 128 129 131 Emission Factor lb/MM Btu NOx I 0.33 I 0.33 I 0.32

### Northshore Mining Barr Engineering Silver Bay, Minnesota February 1, 2006

Table 2 Line 6 (SV261) - NOx Emission Inventory Testing GASEOUS POLLUTANT TESTING December 22, 2005

Test Date 1212212005 12/22/2005 12/22/2005 Run Time 0800-0900 0917-1017 1035-1135 NOx System Bias Calibration, ppm,dry Zero Initial -0.1 -0.4 0.2 Final -0.4 0.2 -0.1 Upscale Calibration Initial 21.9 22.8 23.5 Final 22.8 23.5 23.5 Cal Gas Value 24.8 24.8 24.8
02 System Bias Calibration, %, dry Zero Initial 0.1 0.0 0.0 Final 0.0 0.0 0.1 Upscale Calibration Initial 19.9 20.0 19.9 Final 20.0 19.9 19.9 Cal Gas Value 20.0 20.0 20.0
CO2 System Bias Calibration, %, dry Zero Initial 0.0 0.0 0.0 Final 0.0 0.0 0.0 Upscale Calibration Initial 4.9 5.0 5.0 Final 5.0 5.0 5.0 Cal Gas Value 5.0 5.0 5.0 Measured Concentration Averages Average NOx ppm, dry 23.7 23.6 24.4 23.9 Average 02 19.0 19.0 19.0 19.0 Average CO2 0.8 0.8 0.8 0.8 NOx ppm, dry Bias Corrected 26.3 25.3 25.8 25.8 02%, dry 19.1 19.1 19.1 19.1 CO 2 %, dry 0.8 0.8 0.8 0.8 Volumetric Airflow Rate ACFM 68,206 69,081 68,688 68,700 SCFM 60,073 60,677 60,297 60,300 DSCFM 50,906 51,279 51,150 51,100 Emission Rates NOx, lb/hr 9.6 9.3 9.4 9.4 Process Rates Fired pellets Heat Input MMBtu/hr 102 107 101 103 67 68 68 68 Emission Factor lb/MM Btu NOx I 0.14 I 0.14 I 0.14 0.14

# Figures

## EPA METHOD 2

POINT INSERTION DEPTH INNtoco 

## 2.29
7.51
13.87
23.09
48.41
57.63
63.99
69.21 NO. OF TEST PORTS 2 PORT LENGTH 5" PORT DIAMETER 4" NO. OF TRAVERSE POINTS 16 DUCT DIAMETER 71.5"



# TRAVERSE POINT LOCATION NORTHSHORE MINING SILVER BAY, MINNESOTA #11 PELLITIZER FURNACE WASTE GAS 1 1O4 WWESP OUTLET (SV1 04, EU1 04, CE1 04)

NOT TO SCALE 

# FIGURE 2

## 71.5"

[



## 8.0' ROOF LINE

2 TEST PORTS @ 90°

- , 17.0' 

# T

FURNACE 6



# TEST PORT LOCATIONS NORTHSHORE MINING COMPANY SILVER BAY, MINNESOTA FURNACE 6 HOOD EXHAUST - WASTE GAS (SV261)

NOT TO SCALE 

# FIGURE 3

## EPA METHOD 2

POINT INSERTION DEPTH IN "N)LC)I's--CO 

## 2.29
7.51
13.87
23.09
48.41
57.63
63.99
69.21 NO. OF TEST PORTS 2 PORT LENGTH 0" PORT DIAMETER 4 " NO. OF TRAVERSE POINTS 16 DUCT DIAMETER 71.5"



# TRAVERSE POINT LOCATIONS NORTHSHORE MINING COMPANY SILVER BAY, MINNESOTA FURNACE 6 HOOD EXHAUST - WASTE GAS (SV261)

NOT TO SCALE 

# FIGURE 4

# Appendices

# Appendix A
Report Calculations and Nomenclature

### Northshore Mining Barr Engineering Silver Bay, Minnesota February 1, Northshore NOx Emission Inventory Line 11 Waste Gas Stack (SV104) and *(SV105)
Determination of Volumetric Airflow Rate, Gas Composition and Moisture Content Co. 2006

Run 3 (SV104) Data Entry Symbol Units Run 1 (SV104) Run.1 t(SV105) Run 2 (SV104) Test Date - - 12/21/2005 ..12/21/2005 . 12/21/2005 12/21/2005 Test Period - _ 8:40 .9:O0 H: 10:25 11:45 Number of Sample Ports

. - 2 2 2 2 Number of Traverse Points - _ 16 16 16 16 Duct Dimensions (diameter for circular duct) D inches 71.5 .7t 5 71.5 71.5 Duct Dimensions (length for rectangular duct) L inches Duct Dimensions (width for rectangular duct) W inches Barometric Pressure Pbar in. Hg 29.40 29.40 29.40 29.40 Stack Static Pressure Pg in. H20 0.32 0.45 0.35 0.31 Average Stack Temperature, dry bulb Tsf degrees F 130 132 130 129 Average Stack Temperature, wet bulb Twb degrees F 131 131 131 130 Pitot Tube Coefficient Cp - 0.840 0,840 0.840 0.840 Average Square Root of Velocity Head (AP)^0.5 - 0.767 0,798 0.768 0.767 Orsat Results, Dry Basis Carbon Dioxide %CO2 %v/v 11 1.7 1.7 1.7 Oxygen %02 %v/v 17.1 17,1 17.1 17.1 Carbon Monoxide + Nitrogen - %v/v 81.2 81.2 81.2 81.2 Relative Humidity of Source Gas RH % Vapor Pressure of H20 at Tsf VP in Hg

Calculated Data Symbol Units Run 1 (SV104) Run 1 *(SV105)1Run 2 (SV104) Run 3 (SV104) Duct Area A = (D/24)^2 x PI (Circular Duct) A = (Lx W)/144 (Rectangular Duct) A sq ft 27.88 27.88 27.88 27.88

Stack Pressure Ps 

### = Pbar + pg/13.6 Ps in Hg 29.42 29.43 29.43 29.42

Average Moisture Content of Stack Gas MC = ((VP/Pbar)(RH/100) x 100 MC % Vol 15.4 15.8 15.9 15.6

Molecular Weight of Stack Gas, dry Md = (0.44 x (%CO2))+(0.32 x (%02))+(0,28 x (%N2+%C0)) Md lb/lbmol 28.96 28.96 28.96 28.96

Molecular Weight of Stack Gas, wet Ms = Md x (1-(MC/100))+18 x (MC/100) Ms lb/lbmol 27.26 27.23 27.21 27.25

Average Stack Gas Velocity Vs = 85.49 x Cp x (4P)^0.5 x ((Ts/Ps x Ms)^.5) Vs ft/sec 47.29 49.22 47.38 47.25

Actual Volumetric Flowrate Qa=60xVsxA Qa acfm 79,114 82,349 79,262 79,041

Volumetric Flowrate at Standard Conditions Qs = Qa x (528/(Ts+460)) x (Ps/29.92) Qs scfm 69,390 72,251 69,572 69,513

Dry Volumetric Flowrate at Standard Conditions Qd 

### = Qa x (1-(MC/100)) x (528/(Ts+460)) x (Ps/29.92) Qd dscfm 58,677 60,871 58,503 58,689

### Northshore Mining Silver Bay, Minnesota Northshore NOx Emission Inventory Line 6 Waste Gas St6 (North Stack) Determination of Volumetric Airflow Rate, Gas Composition and Moisture Content Co. t006

Data Entry Symbol Units Run 1 (SV261) Run 2 (SV261) Run 3 (SV261) Test Date - - 12/22/2005 12/22/2005 12/2212005 Test Period - 8:10 9:25 10:45 Number of Sample Ports - 2 2 2 Number of Traverse Points - - 8 8 8 Duct Dimensions (diameter for circular duct) D inches 71.5 71.5 71.5 Duct Dimensions (length for rectangular duct) L inches Duct Dimensions (width for rectangular duct) W inches Barometric Pressure Pbar in. Hg 28.85 28.85 28.85 Stack Static Pressure Pg in. H20 0.31 0.32 0.29 Average Stack Temperature, dry bulb Tsf degrees F 119 120 120 Average Stack Temperature, wet bulb Twb degrees F 118 120 120 Pitot Tube Coefficient Cp ,_ 0.840 0.840 0.840 Average Square Root of Velocity Head (AP)^0.5 ,_ 0.662 0,669 0.666 Orsat Results, Dry Basis Carbon Dioxide %CO2 %v/v 0.8 0.8 0.8 Oxygen %02 %v/v 19.1 19.1 19.1 Carbon Monoxide + Nitrogen - %v/v 80.1 80.1 80.1 Relative Humidity of Source Gas RH % Vapor Pressure of H20 at Tsf VP in Hg

- Calculated Data Symbol Units 'Run 1 (SV261) Run 2 (SV261) Run 3 (SV261) Duct Area A = (D/24)^2 x PI (Circular Duct) A = (L x W)/144 (Rectangular Duct) A sq ft 27.88 27.88 27.88

Stack Pressure Ps = Pbar + Pg/13,6 Ps in Hg 28.87 28.87 28.87

Average Moisture Content of Stack Gas MC = EPA M-4 Moisture Train MC % Vol 15.3 15.5 15.2

Molecular Weight of Stack Gas, dry Md = (0.44 x (%CO2))+(0.32 x (%02))+(0.28 x (%N2+%C0)) Md lb/lbmol 28.89 28.89 28.89

Molecular Weight of Stack Gas, wet Ms = Md x (1-(MC/100))+18 x (MC/100) Ms lb/Ibmol 27.23 27.20 27.24

Average Stack Gas Velocity Vs = 85.49 x Cp x (AP)^0.5 x ((Ts/Ps x Ms)^.5) Vs ft/sec 40.77 41.29 41.06

Actual Volumetric Flowrate Qa = 60 xVs xA Qa acfm 68,206 69,081 68,688

Volumetric Flowrate at Standard Conditions Qs = Qa x (528/(Ts+460)) x (Ps/29.92) Qs scfm 60,073 60,677 60,297

Dry Volumetric Flowrate at Standard Conditions Qd = Qa x (1-(MC/100)) x (528/(Ts+460)) x (Ps/29.92) Qd dscfm 50,906 51,279 51,150

### Northshore Mining Barr Engineering Co. Silver Bay, Minnesota February 1, 2006 Northshore NOx Emission Inventory Line 6 Waste Gas Stack (SV262) (Middle Stack) Determination of Volumetric Airflow Rate, Gas Composition and Moisture Content

Data Entry Symbol Units Run 1 (SV262) Run 2 (SV262)
Test Date - - 12/22/2005 12/22/2005
Test Period - - 8:20 9:45 Number of Sample Ports - - 2 2 Number of Traverse Points - - 16 16 Duct Dimensions (diameter for circular duct) D inches 71.5 71.5 Duct Dimensions (length for rectangular duct) L inches Duct Dimensions (width for rectangular duct) W inches
Barometric Pressure • Pbar in. Hg 28.85 29.40 Stack Static Pressure Pg in. H20 0.34 0.34 Average Stack Temperature, dry bulb Tsf degrees F 121 121 Average Stack Temperature, wet bulb Twb degrees F 120 121 Pitot Tube Coefficient Cp - 0.840 0.840 Average Square Root of Velocity Head (AP)^0.5 - 0.640 0.633 Orsat Results, Dry Basis Carbon Dioxide %CO2 %v/v 0.8 0.8 Oxygen %02 %v/v 19.1 19.1 Carbon Monoxide + Nitrogen - %v/v 80.1 80.1 Relative Humidity of Source Gas RH % Vapor Pressure of H20 at Tsf VP in Hg

Calculated Data Symbol Units Run 1 (SV262) Run 2 (SV262)
Duct Area A = (D/24)^2 x PI (Circular Duct) A = (L x W)/144 (Rectangular Duct) A sq ft 27.88 27.88

Stack Pressure Ps = Pbar + Pg/13.6 Ps in Hg 28.88 29.43

Average Moisture Content of Stack Gas MC = ((VP/Pbar)(RH/100) x 100 MC % Vol 11,9 11.7

Molecular Weight of Stack Gas, dry Md = (0.44 x (%CO2))+(0.32 x (%02))+(0.28 x (%N2+%C0)) Md lb/Ibmol 28.89 28.89

Molecular Weight of Stack Gas, wet Ms = Md x (1-(MC/100))+18 x (MC/100) Ms lb/Ibmol 27.59 27.62

Average Stack Gas Velocity Vs = 85,49 x Cp x (0) 1 '0.5 x ((Ts/Ps x Ms)^.5) Vs ft/sec 39.24 38.40

Actual Volumetric Flowrate Qa= 60 xVsxA Qa acfm 65,654 64,250

Volumetric Flowrate at Standard Conditions Qs = Qa x (528/(Ts+460)) x (Ps/29.92) Qs scfm 57,611 57,433

Dry Volumetric Flowrate at Standard Conditions Qd = Qa x (1-(MC/100)) x (528/(Ts+460)) x (Ps/29.92) Qd dscfm 50,750 50,719

### Northshore Mining Barr Engineering Co. Silver Bay, Minnesota February 1, 2006 Northshore NOx Emission Inventory Line 6 Waste Gas Stack (SV263) (South Stack) Determination of Volumetric Airflow Rate, Gas Composition and Moisture Content

Data Entry Symbol Units Run 1 (SV263) Run 2 (SV263) Test Date - _ 12/22/2005 12/22/2005 Test Period - - 8:35 9:35 Number of Sample Ports - - 2 2 Number of Traverse Points - 16 16 Duct Dimensions (diameter for circular duct) D inches 71.5 71.5 Duct Dimensions (length for rectangular duct) L inches Duct Dimensions (width for rectangular duct) W inches Barometric Pressure Pbar in, Hg 28.85 28.85

. Stack Static Pressure Pg in. H20 0.41 0.40 Average Stack Temperature, dry bulb Tsf degrees F 121 121 Average Stack Temperature, wet bulb Twb degrees F 120 121 Pitot Tube Coefficient Cp - 0.840 0.840 Average Square Root of Velocity Head (AP)^0.5 - 0.709 0.703 Orsat Results, Dry Basis Carbon Dioxide %CO2 %v/v 0.8 0.8 Oxygen %02 %v/v 19.1 19.1 Carbon Monoxide + Nitrogen - %v/v 80,1 80.1 Relative Humidity of Source Gas RH % Vapor Pressure of H20 at Tsf VP in Hg

Calculated Data I Symbol Units Run 1 (SV263) Run 2 (SV263) Duct Area A = (D/24)^2 x PI (Circular Duct) A = (Lx W)/144 (Rectangular Duct) A sq ft 27.88 27,88

Stack Pressure Ps = Pbar + Pg/13.6 Ps in Hg 28.88 ' 28.88

Average Moisture Content of Stack Gas MC = ((VP/Pbar)(RH/100) x 100 MC % Vol 11.9 11.9

Molecular Weight of Stack Gas, dry Md = (0.44 x (%CO2))+(0.32 x (%02))+(0.28 x (%N2+%C0)) Md lb/Ibmol 28.89 28.89

Molecular Weight of Stack Gas, wet Ms = Md x (1-(MC/100))+18 x (MC/100) Ms lb/Ibmol 27.59 27.59

Average Stack Gas Velocity Vs = 85,49 x Cp x WM.5 x ((Ts/Ps x Ms)^.5) Vs ft/sec

. 43.43 43.13

Actual Volumetric Flowrate Qa= 60 xVsxA Qa acfm 72,653 72,161

Volumetric Flowrate at Standard Conditions Qs = Qa x (528/(Ts+460)) x (Ps/29.92) Qs scfm 63,774 63,265

Dry Volumetric Flowrate at Standard Conditions

, Qd = Qa x (1-(MC/100)) x (528/(Ts+460)) x (Ps/29.92) Qd dscfm 56,179 55,730

### Northshore Mining Barr Engineering Line 11 Waste Gas Stack January 30, 2006



### RESULTS OF STACK MOISTURE DETERMINATIONS Line 11 WG Stack (SV 104) Test Date. 12/21/05 RUN 1 (0835-0935) RUN 2 (1015-1115) RUN 3 (1135-1235) Meter Volume Vm, fr Orifice

. DH, in H 2 O Stack Temp.

(°F) lmpinger Temp.

(°F) Meter Inlet (°F) Meter Outlet

(°F) Meter Volume Vm, fr Orifice DH, 

### in H 2 O Stack Temp.



### (°C) Impinger Temp.

(°F) Meter Inlet (°F) Meter Outlet

(OF) Meter Volume Vm, fr Orifice DH, in H 2 O Stack Temp.

(°F) Impinger Temp.

(°F) Meter Inlet (°F) Meter Outlet

(°F) 278.92 324.14 369.27 282.57 2.0 130 53 69 68 327.84 2.0 130 51 69 69 373.16 2.0 129 52 70 69 286.35 2.0 130 41 70 68 331.62 2.0 129 41 69 69 376.94 2.0 129 43 70 69 290.11 2.0 129 40 72 68 335.42 2.0 130 40 70 69 380.69 2.0 130 45 72 68 293.85 2.0 130 41 74 69 339.16 2.0 130 42 72 69 384.48 2.0 130 47 73 68 297.61 2.0 130 42 76 69 342.87 2.0 130 44 74 69 388.32 2.0 129 47 74 68 301.32 2.0 130 43 77 70 346.61 2.0 130 45 75 69 392.01 2.0 130 47 74 68 305.10 2.0 130 43 78 70 350.34 2.0 129 45 75 69 395.87 2.0 130 48 74 68 308.98 2.0 130 44 79 71 354.05 2.0 130 45 76 69 399.52 2.0 129 48 75 68 312.62 2.0 130 44 79 71 357.81 2.0 130 46 76 69 403.26 2.0 130 49 74 68 316.40 2.0 130 44 80 72 361.55 2.0 130 46 77 69 407.01 2.0 129 49 74 68 320.18 2.0 130 44 80 72 365.29 2.0 130 47 76 70 410.47 2.0 129 49 74 68 323.95 2.0 130 43 80 73 369.01 2.0 130 47 76 70 414.46 2.0 129 49 74 68 Total Meter Volume Vm, 

### ft Average Orifice

DH, in H 2 0 Average Stack Temp.

( ° F) Average lmpinger Temp.

(°F) Average Meter Temp.

(°F) Total Meter Volume Vnn, ft 5 Average Orifice

DH, in H20 Average Stack Temp.

( ° F) Average lmpinger Temp.

(°F) Average Meter Temp.

(°F) Total Meter Volume Vm, ft 6 Average Orifice

DH, in 

### H 2 0 Average Stack Temp.

(°F) Average lmpinger Temp.

(°F) Average Meter Temp.

(°F) 45.03 2.0 130 44 73.13 44.87 2.0 130 45 71.46 45.19 2.0 129 48 70.67 Moisture Recovery Data: Moisture Recovery Data: Moisture Recovery Data: lmpinger 1 2 3 Desiccant Total lmpinger 1 2 3 Desiccant Total lmpinger 1 2 3 Desiccant Total Final 256 104 0 1067 Final 254 112 0 1077 Final 256 108 0 1086 Initial 100 100 0 1057 Initial 100 100 0 1067 Initial 100 100 0 1077 Diff, 156 4 0 10 170 Diff. 154 12 0 10 176 Dill. 156 8 0 9 173 Standard Meter Volume 43.81 Moisture Content (%v/v) 15.44 Standard Meter Volume 43.79 Moisture Content (%v/v) 15.91 Standard Meter Volume 44.17 Moisture Content (%v/v) 15.57 Barometric Pressure (in Hg) 29A0 Barometric Pressure (in Hg) 29A0 Barometric Pressure (in Hg) 29A0 Meter Coefficient 0.9948 Meter Coefficient 0.9948 Meter Coefficient 0.9948Northshore Mining Barr Engineering Line 6 Waste Gas Stack January 30, 2006



### RESULTS OF STACK MOISTURE DETERMINATIONS
Line 6 WG Stack (SV261) Test Date: 12/22105
RUN 1 0800-0900 RUN 2 0917-1017 RUN 3 1035-1135 Meter Volume Vm, ft Orifice DH, in H 2 O Stack Temp.

(°F) Impinger Temp.

( ° F) Meter Inlet (°F) Meter Outlet

(°F) Meter Volume Vm, 

### ft Orifice DH, in H 2 O Stack Temp.

(°C) Innpinger Temp.

(°F) Meter Inlet ( ° F) Meter Outlet

(oF) Meter Volume Vm, fr Orifice DH, in H 2 O Stack Temp.

(°F) Impinger Temp.

(°F) Meter Inlet (°F) Meter Outlet

(°F) 414.76 460.18 505.82 418.47 2.0 - 118 47 64 64 463.97 2.0 118 58 73 70 509.68 2.0 117 57 73 71 422.21 2.0 117 41 64 64 467.75 2.0 118 45 73 70 513.51 2.0 117 48 73 71 425.98 2.0 118 40 66 64 471.46 2.0 117 45 75 70 517.30 2.0 117 50 75 71 429.76 2.0 117 42 68 64 475.23 2.0 117 46 77 71 521.08 2.0 118 51 77 71 433.53 2.0 117 43 70 65 479.01 2.0 117 48 77 71 524.84 2.0 118 52 78 72 437.28 2.0 117 44 71 65 482.80 2.0 117 49 78 71 528.62 2.0 118 52 78 72 441.09 2.0 117 44 72 66 486.57 2.0 117 50 78 71 532.46 2.0 118 52 79 72 444.84 2.0 117 45 73 66 490.31 2.0 117 51 78 72 536.27 2.0 117 52 79 72 448.53 2.0 117 46 74 67 494.10 2.0 117 52 78 72 540.08 2.0 117 52 79 73 452.30 2.0 117 46 75 67 497.91 2.0 117 53 79 72 543.87 2.0 117 52 80 73 456.05 2.0 118 47 75 68 501.68 2.0 117 54 79 72 547.65 2.0 117 52 80 73 459.77 2.0 117 47 77 69 505.46 2.0 117 54 79 72 551.44 2.0 117 51 81 74 Total Meter Volume Vm, ft j Average Orifice

DH, in H 2 O Average Stack Temp.

('F

. ) Average Impinger Temp.

(°F) Average Meter Temp.

(°F) Total Meter Volume Vm, ft Average Orifice

DH, in H 2 O Average Stack Temp.

(°F) Average lmpinger Temp.

(°F) Average Meter Temp.

(°F) Total Meter Volume Vm, ft'' Average Orifice

DH, in H 2 0 Average Stack Temp.

(°F) Average Impinger Temp.

(°F) Average Meter Temp.

(°F) 45.01 2.0 117 44 68.25 45.28 2.0 117 50 74.08 45.62 2.0 117 52 74.88 Moisture Recovery Data: Moisture Recovery Data: Moisture Recovery Data: Impinger 1 2 3 Desiccant Total lmpinger 1 2 3 Desiccant Total Impinger 1 2 3 Desiccant Total Final 246 108 2 1064 Final 248 110 

### o 1074 Final 248 108 0 1083 Initial 100 100 

### o 1054 Initial 100 100 0 1064 Initial 100 100 0 1074 Diff. 146 8 2 10 166 Diff. 148 10 0 10 168 Diff. 148 8 0 9 165 Standard Meter Volume 43.37 Moisture Content (%v/v) 15.26 Standard Meter Volume 43.16 Moisture Content (%v/v) 15.49 Standard Meter Volume 43.42 Moisture Content (%v/v) 15.17 Barometric Pressure (in Hg) 28.85 Barometric Pressure (in Hg) 28.85 Barometric Pressure (in Hg) 28.85 Meter Coefficient 0.9948 Meter Coefficient 0.9948 Meter Coefficient 0.9948

# Appendix B

Field Data Sheets

## BARR ImIllmsnong Project 

## s / 1 1 Sample Location frIx h 6 5 Date 

## and. F Operators 

## LYTK Duct Dimensions Port Length 

### 2C Pitot Tube No. 

### 17- Cp Manometer ID 

### p ) c 1 

### H Digital Therm ID 

## D inches inches

Bar. ID ty , y1c T.C. ID 

### EPA METHOD 2 FIELD DATA SHEET , • Run 1 Run 2 Run 3 Run 4 Bar Press (In Hg) 

### 2- 4 1.5 f '1.1. Y 24. y 

### 29,v Stat. Press (In H 2 0) 0.3t (.), 

### / 3 /,‘. 6.3 1 36,4 j3 2.. Temp - Dry Bulb 2 F 13 

### 2- Temp-Wet Bulb 9 .F / 

## V /3/..1 I 30. 0 ii 1
Moist Content - % /6 1 g /6: /( 1 -. . 4 1 t6r5 0 2 % i 1, I / 

## 7-il 1?-4 )7,1
D960 Time of Meas. 0 S4c' 1 0 ZS MS —

Pitot Leak Check Positive: Z.) if-- Negative: O zAv Traverse Point Information Cyclonic Flow Z 9 Velocity Head - Inches H 2 0 Stack Temperature - 2 F Point Number Inches From: Run 1 AP Run 2 AP Run 3 AP Run 4 AP Run 1 Temp. Run 2 Temp. Run 3 Temp. Run 4 Temp. Wall Port 

# PT — I 22 

# 6. cy 0,3 

## 2_ b

. 2..v b..2.,3 t.. , -/y

. Ii.3L 0 

### ..ii 0 

### ..s' , o..1C 3 

### i3.0 ics.12- t.€4 , 5 C-s — 0.65 - . , Ssk 4' 2.09 23,351 k,( s ,‘ ..,, (..t. t.iz b•1 0
3— 1 1 5 104 5 2 ;(0\n& • 

### t-.10(. 6 s-3:63 (.1.i5q D. (6s — t.,LIA 6



### . (I c,. 

# 7. 0,cli ( 6

- -2 -`( c>.bc olo , °. 0 L. 

## sr % 

# (Az( 71-‘1L 6.3 ( 6 6 

### .SY "' 91 0



### . 3 ct 

# 6- t)33. o.ly , 0:-/ti b, Liy • 2 6 •/S .— 0 -L1. 

## 0 .(31

3 

### C.1:3

- 

### 1 

### D,Let' t',C45" t...(..1

ce o‘C ( ‘

. 

### k..6.cis
, iN.LI. b , 

### TY


## C ' D (3,3 O,LY

- 

## a

- 0. 

### 5:5 - 

### b3 (,I 0,51 0 

### .Sic 0,9y

....

•

Run 1 Run 2 Run 3 Run 4 Stack Pres. - In Hg 

### t5„qz, 

# zy. y2 Efflia
Duct Area - S Ft. MU 21-.. r-k 

### WEI 24, gc r

### Mole Wei ht - Md 245% 5*

- 

### 3 .4' 

# primmyywrimmr. Z 

### 5

- " , 5

- ‘•

MaglillagnIM 

# emingrancr i ngs IMMIKETIMINIE IMMITIMI

6. Mole Wei ht - Ms 

# A, . Tem . - 9 F Average N.FAITi Gas Vel - Pt/Sec ACFM 

# n MI

. SCFM 0 

### ( 

### i 57Zraggi

- 

### 7

. ? 251

DSCFM 51c G 

### 7 

# rini cia,g-5. (..,57- I
Schematic of Duct Cross-Section

### Moisture Recovery Data: Impinger 1 2 3 4 • Desiccant Total I Final wt., g 251,, i CW o Initial wt., g jo so i czt; C Afft

. f 

### Or I - Difference is - 

## ii,.

. Y i e!, 

## I 11) Integrated Gas Sampling Data: Box No. Bag 

### No. Bag Vol. Leak Rate, cc/min 02 Reading 02 Analyzer No. at 15 in Hg 

# EPA METHOD 4 BARR 

# FIELD DATA SHEET

Project 

## 4V-30 , 1 , S\"1.- A/1) CM 

## ,c SM P Pitot No. Op 

## ' Sample Train Leak Rate (cfm) , ,--- Sample Location 

## t_;.,,. 0 1 b.) (.., - Ski ioti Meter y 

### 01 1 'tq Bar. Press. 

### 2c1 , Ya , in Hg 

### Date i /N0'3 ,- 

### Test 

## i Run 

## i Orifice AI

- I @ 

## I , Wc. , 5 - Posttest P retest e s at 15 in Hg 

## 6

0

. . , 6

)

at 

## -S7in Hg Operators 

# b

. )-K. Eff. Probe Length ft Liner Type:0 Glass 0 S.S. 0 Other

Sample

Point Sample Time

AT Meter Volume Vm, liters Meter @ H Iv. H20 Sample Vacuum,

in Hg Stack Temp. Ts, °F Sample Train Temperatures, °F Oxygen Content, % Probe Filter

. Impinger Outlet Meter Inlet Meter Outlet
RON. 1 

### .1 0 1 ( O S S 3



# r ) 

# (27'11 ) 

# 1,4 "I" 

# _.....: 1.1 

### - Pose l' ]1' !' - - 

### w, 

# A- C, ...S"

- .zcl.57-- A.;' Z , c ' I • 1 

### 130 "g5 , -;'

, 

### 7. s

- -:)

. .5

- 3 (..c: , `Y 

### C 4‹ 5 - 

### 31 3.1% I

.. 

### )36 2ç. 2. S'z tit 5 1 / "-- 

### J, .1 I ?ci 

# 2 r., 7 

# rs , vo 3Z 3 Z. • ' .- IPSS -- 

### 31=1 I, <3 i 

### 3 e

.. 

### 'z li?

- 

### z.ft 4 

## V/ Y. ( et. Z 2N' 

### 1.41 , 61 5, -, N , t , c. 1 1 Z

. 5- ..) i f-a 

### 9'2 6 

## 61. '2._ 1.94 ,. ,;, i 

### 3 

### - G c 3t.. -c- J

. :. S .1 8 /., )3. ZS'.-1 Z s0 

### V3 1- f? 10
c tt, 36V , e l s‘ 543 0.. 13

. - 

### Zs - ...; z .-ri ciV 31 1 1 Y I"— 1111-,L2.. , I..) i 

### 1.3 'Z.

- r , ) 

# 3:14 U. ----' )1 J 2 To 7 r..) 

# 7

. >- sp 3 L z 5.c 3*

- 4- 0`4,

- 

### 3,1'1 , 0,.D 1

- z,3 

# -2. r‘._., 7.'11 YY 

## 4-1- 3V•el 

# r 1,31

. 1, e 1 3 3 25%) 2 5

- .. 1'3 7 

## 13

• Ø=Cy3S - Vm= 1 /5"..0 

# sFr= a ,. Ing, fill 'n= i 

## 3. .4-,' 

# Nil PS MINVOININ ' 1 ' c. ''' 'INEMINN, rrn=4 3 

# I iii„,,, m 6

### Box No. Bag No. Bag Vol. at 15 in Hg 

### Leak Rate, cc/min 02 Reading 02 Analyzer No. 

# BARR

7 

### Project 4/ .911 ,A.A_ ( 1 1: , -;..1 s CM - 5- SM P_ Pitot No. Op Sample Train Leak Rate (cfm) Sample Location L;v r , 

### 1( tt.31
, - 

## -S -1-,k iv41, Meter 

### y 0, 

## 51YS Bar. Press. 2 9 , Y in,Hg Pretest t,C 3 at 15 

### in Hg
Date 

## 12. - z 1-os - Test 

### ( 

## Run Z... Orifice AN @ helY t r - Posttest t) c. atS in Hg Operators 03

- 1c/ Eff. Probe Length ft Liner Type:El Glass El S.S. 0 Other

Sample

Point Sample Time

AT Meter Volume Vm, liters Meter @ H Iv. H20 Sample

. Vacuum,

in Hg Stack Temp. Ts, °F Sample Train Temperatures, °F Oxygen Content, % Probe Filter lmpinger Outlet Meter Inlet Meter Outlet
' totl ( K , 15 - ) ( 3 2 `t J`f ) t, ¶ i14]...:,- [ )

. , 111 t , ,r111 ' ' 

# I MIL ...1:... 1 L'

- 5'• .3z18

- Y

. 

### 3AD 7. r:- ., 

## 1.a. 1

. 3c. Z..s

- c. zs 0 sl 6 1 cv 01 3S1.(11. A 1.n. il 6 1 7, C
, -> Z ) ..- --.3 

### e it 

## 6 9 C cl
I 

### $' 33 5- .1 7.. 3.F , 

## Y I , ;:, 13o 2.5. ts'i 3 z- 334. ti, 3.14 i z. il , - 1 2 

### - " z 

### re V Z.. 

### '.•. Z. C,9 Z 2 ,-- 54 2 -131- 311 i -‘3 is , .. 25 -. ..)

t 3 ---..., 341.i.-1 /11 1 . 

### 1.3.. z r. rz. .7 ,e, 3,i t( 1.43 Y. s 

## i'2 2co IS I 

## Vr 1 S - C ci

c y , . 35%).t. r 3,70 I ,... 

### 13 "2_c.> 

### 1.. V1 v 5 *- q• IL., Cali 2.c. 2. Yti 96 31, C,cf 3 .5." NI. 

## s .41 1. .-.. 13•:s 7- 5" '. . z i' .3 q G 

### ?- 7- (II • Z. c5 - 3Gc.z.ei 3.11 ;,,t, )30 Z s

- .- 7.„ kic‘ I I-



## , IA.° 1 . .1z- 

# + • i . 4 • 130



### Vnn=q 1 / 

## Vr Ail= 2.,. It 9 1 !1 i'lllik:], ,, rS= III „ CI - T I , ,-.11,1i ' = 

# EPA METHOD 4 FIELD DATA SHEET

Moisture Recover Data: Impinger 1 2 3 4 Desiccant Total Final wt., g t5'4 117— it, 74

. 73_ 1, P

. 

### Initial wt., g )01 / 0 ;) 

### 0 

### Difference I s 4 i -7.- o 1 n , 1(:) 

### Integrated Gas Sampling Data:

### Moisture Recovery Data: Imping4 .

. '1 2 3 4 Desiccant Total Final wt., g 

### 15"L it 1:r

. 0 la 5 3 (a tfi Initial wt., g /N: i ‘.0 

# P 4> A 1... , :4

- . 1- Difference Is‘,.. %, k. 9 / 

# 43 

# EPA METHOD 4 FIELD DATA SHEET 

# BARR
Project sli (in .1; , ) CM S- SM P Pitot 

### No. Sample Location C. N .c. It 44-41. Meter y b‘ c lI t a 

### Bar. Press. Date 

## fajzti.r - Test 

## i Run 

## 3 Orifice AH @ /, Operators 1))t._ Eff. Probe Length ft Liner Type:0 Glass 0 S.S. 0 

### Other Op Sample Train Leak Rate (cfm) in Hg Pretest O. at 15 in Hg Posttest 4

- ) at in Hg

Oxygen Content, %• 

### Sample Train Temperatures, °F Stack Temp. Ts, °F Sample Vacuum,

in Hg Meter

@ H Iv. H20 Meter Volume Vm, liters 

### (36 c 111% 

## ) Sample

Time



### ( 11 3 r ) Sample

Point Impinger Outlet Meter Outlet Filter Meter Inlet Probe



## 5 Z_ 3. 4

§I 2.z. 1 

### g -

4 3 -1(43 2. S‘I. ) 

### I ,e4 

### 9' 

## 3 

## a.T4 3 

## 9 6.9 Y i24' Z 

### yi7 13Q
, 

### S

- z 3$t) , V1 Z 

### 32 

### al( ti 

### 3%* L/Y ‘i 

### 3.,1q 3 lvt 

## 3A 5 z- S.;) 

### z. 3.`6Y 

### (IV 

## "9- 12. , 14 

### z 

## 3 JO 4 1

.%.1 

### Zr4 130 V 

### 1 ti5" 3 r 

## P. 110 5" 12 

### 9 y 

### 7 c `7( 

## Y tios 

## .3.4y 

## z Y 13% 

### G 

## 91 2 Ss 

## z Z. ) 2,4 

### C 

## rd 4%. 2. S'Ll 

### 2;4'1 12.9 

### YI0 , 11" t1/4. 4 1‘ 

## 341-1- 2



### 4, IMP ,SIT= •Z,:
, .1 ,, = 

# '*H'illiltlii'ii'IP ._rf,' ;' , 4191

- Ill I'. .1,4 t ....., „, ri 411.1.E., ' 1- 

# ,,, , 4 - ,1 

### Integrated Gas Sampling Data: Leak Rate, cc/min 02 Reading 02 Analyzer No. Box No. Bag No. Bag Vol. at 15 in Hg

### 1-3Y. T-11 I eak C Positive: b 

### /C- Negative: 0 k. Bar Press (In Hg) ZS. ( 61 Stat. Press (In H 2 0)
Tem - D Bulb 2 F Temp - Wet Bulb 2 F

Moist Content - % 0 2 % Time of Meas.

t Traverse Point Information Cyclonic

L 2 Flow Velocity Head - Inches H 2 0 Stack Temperature - 2 F Point Number Inches From: Run 1 AP Run 2 AP Run 3 AP Run I AP Run 1 Temp. Run 2 Temp. Runt Temp. 

### 03z Run 4 Temp. Wall Port
Z 7-1 4 

### 031 COZ b.3 1 

## 6.3.- 0.3z b,21. 7_ 

### Y 1 

## o.to t.ki. cl.Liz O, 

### 0,

- zei 0,31 S 13.s33 3 0.y? O.Y% 1/4%.5 -4 bt e “ 

### cl.51 031 - t.) .ciLi 210.1 A , s-3 0. cz_ $3, S 1_ 0, i 

### f 

## 7- c((
"t15 0 ‘ 6° 0 .Cfr's k. Cu G ' s33-.; 

### 0 0,41 G. 

## 5 7 - 6`9.1 t'4'1. 

### 6 ' get 

### a.95 - b'Cl 

### Of a . irl tf., Vt„, 

### 0, VI O, VS

C1:21

- 5— 

### c).Y/ 1.t.3i b. 

## 3% 0-31 - 6 , 0 t 

## 3-1. 0,v , 4. 6,11 6.17- ID. 3( 0,2.9 b8 2 5,71 

### 6, VI 

## 0.3y b,, go , tic, 6 

### , 3 s - 

## 6.rf 0 :53 e. V4 3 . -- 0.tpi o At 

## kl, '17 0

. ( 1 5- °, 5Y -- 0,Efe/ 1)43 Y t , •5

- 1 0. S

- 1_ 0..sez 0 

### 4

- ir DA - (. 0,y( r , r “'t t e., 5

- 3 0. c3 0 Vi - b.C3 . 0.91 04. t

. 

# c et. •ki 1 0 . 

## IN o. yi d zoti... u,(,z. 0 . 

## y s

- 

## ? o ‘ air 0. V3 oi Yy 0 , 95 - 6,S , f. o.y

. 

## c5 - 0.3i 0.3ck (3,3 , o!((a, 

## c›13 0, v 1

CI

,.., .c rf

.

- •••7 — 3

I 

### BARR
Project 

### i,sv S Sample Location le. Date 

### 121 

## 41- 5 - Operators 

### 1PIL Duct Dimensions Port Length Pitot Tube No. Manometer ID Digital Therm ID inches 0 inches Cp 

### S' ■ 

### 1 

## 14 Bar. ID T.C. ID 

### EPA METHOD 2 FIELD DATA SHEET -ELI Vct, L.l 

### 2-48 - ze - 1

- Run 1 

## 7.4.2 3 1 .1 " -- 2(

0 2- Zer -1(cg.

Schematic of Duct Cross

- Section Run 1 Run 2 Run 3 Run 4 Stack Pres. - In Hg Duct Area - Sq Ft. Mole Weight - Md Mole Weight - Ms Avg. Ternp. - 2 F Average \TAT Gas Vel - Ot/Sec ACFM SCPIVI DSCFM

# EPA METHOD 4 FIELD DATA SHEET 

# BARR '

Project 4

. ), v A 3 1 1,./N / 1 1: "1:-'1 ( 

# cm .S - SM P Z Pitot No. 

## I' Cp O. 

## Y Sample Train Leak Rate (cfm) Sample Location 1.:.1c.. (c, 

## 1.06-5 Meter y (:), 

## q 9 ‘1% Bar. Press. 

## 2`%-'53r in Hg Pretest 0



## . 6 at 15 in Hg Date 

## iLiztla

- s — Test 

## 2_. Run 

## I Orifice 6,H @ 

## 1. `N Posttest 0



## . 0 at 1 in Hg Operators 

## t "i• 1r Eff. Probe Length ft Liner Type:0 Glass IXS.S. 0 Other

Sample

Point Sample Time •

AT Meter Volume Vm, liters Meter @ H Iv. H20 Sample Vacuum,

in Hg Stack Sample Train Temperature, °F Oxygen Content, % Temp. Ts, °F Probe Filter lmpinger Outlet Meter Inlet Meter Outlet

_ IV 

### ' it ( "010 0 ) ( 1 45/.1

- ( 

## ) '4,1 1-, :xic

l!ii4,11MN,,to-):,iiit, 

## tr

. '';';' , Iiiiiii.4 

## I '' , .iltai;

. , 

### ellg. 9 4 V) Z. 0 1,c , 

## 2.5- //2 2.5-.) Z7> 

### Y7 

# c , 3 yz z . t 1 S.1 4 1 1. .. 1i1 25

- a. z 5 

# ' Y/ Co 

### Y 

# G it 2 S 

### 3 

## 2 1 

## V2
, 1,1A. Vis 1.,‘ 1); 

# z )

- 3 15'1 V Z ic 

# y t/33, 53 3, 1.4 ),t; 1)4 'z ga Z5 

## 4/3 '1 , - 

### .z itoSs 

### I 3 s• 

### Y14 , 'z.`76 S.35

. i.. I 11- Z5 z Sz 

## yy 9- I (es ir VIII 

## ,01 1,c41 'IA 

## 1/1 Z la °Z 

# r I '444. 

## ekt 3:+s- 0
4-.3 3,b1 1..o it r 1.- Z1. 2. S

.. . C i t let 

## 4 Y
1 

### 151,3o 

### 14-1- 1_ a • 11 

### 1- 1 5•Q 

### 2. S tit. 3 5- 

### z_ -fr - /S -6 .-1 - 3:4T I 6 0 

### V591

- 4- 3- 4i- -, 1 ‘, 0 / t 

### 4
•



# , .
g= ocio vm=y5..i SF= 

## ' 7 % ,6 [ ,,Ir wlir"

. = 1, 

# lii 1

Moisture Recover Data: Impinger 1 2 3 4 Desiccant Total Final wt., g 

### 246 

### 10 4

. 7_ 1° 1 .01 1 

### Initial wt., g (Ns '0 1 , 34 

# r) /Ph' itcq

, 

### Difference 

### Integrated Gas Sampling Data: Box No. Leak Rate, cc/min Bag No. 02 Reading Bag Vol. 02 Analyzer No. at 15 in Hg

# EPA METHOD 4

Box No. Bag No. Bag Vol. at 15 in Hg Leak Rate, ccimin 02 Reading 

### 02 Analyzer No. 

# E3ARR

Project 

## A),4.,c1 ) ,,,.. /14. 

# cm 5 — sm P - Pitot No. 

## )1 - Op 0



## . t aI Sample Train Leak Rate (cfm) Sample Location 

## I.Q6,5 Meter y 

### t3.9'

- \

1 / 4 1i Bar. Press. 

## 2 &WC - in Hg Pretest 0.2 , -) 

### at 15 in Hg Date 

### 12



## - '2.1



## - r Test Run - 2- 

### Orifice AH @ 

## L. ti Posttest 6- 

## ' 1 at /' in Hg Operators 

### ,rp, tc,„ • Eff. Probe Length ft Liner Type:0 Glass S.S. 0 Other

Sample

Point Sample Time

AT Meter Volume Vm, liters Meter @ H Iv. H20 Sample Vacuum,

in Hg Stack Sample Train Temperatures, °F

, Oxygen Content, % Temp. Ts, °F Probe Filter Impinger Outlet Meter , Inlet Meter Outlet
' 

# Mk ( z1ri- ) ( qt2t , is)
_....,„ ,...„. 4 N :3 ' 

# g 

# ' A-. c 4631'1- z.



## , 1.3 

## 31q lig 253 

## 2 cs ., 

## ss 3 1 1=z5

- Li.) 1 Vis 2.5" 

## z y1 Y c 4 3 7 , 3 V
, 

### s - 91P1L, 3.11 5 2.... ylf.z. 5 :3.11- /.., 

## rn- 1 3... z 9 Ylv T.71- 3 ' ( 

### 14-q,c• 1 

## 3.3a. 1.. 1 /I 7. 1-4 

## z r 1 Y $ 3 

### 3- 31

( 

## 9101 0 3:3'1 I. ill13- L 

## 3c - nb , s1 1,3 1-: 1.a, 1 II-.

- 

## zs - z•

- 

## z._•?
, 9 ■ 

## S' 

## 7 w 3-1
Y. tric3,3 I 3 ,3f 1.5"' )0- 2$ 2 

## yl Yi I V 4z t-f Yr Y c r1.1 6 3. 3 1 t, g -- • 1)1- Zs

. an g 2_ 

### 7 3 

## 5 -, 91111 3...R.1 1,5 — III- • s 3

. "2-

- 15 

### 5 3 1 i 

## 7 a •
1. 

## s- s - .reli:taS S-11 - 111- 2 s

- ..v 

### Z50 S 

## y 

## 4 1 qz 3oSN 1

. 3.1 k< tt) 1- 5 — 111- 1 

### SL 

### "ZS' I CY • '3- i 1 z•

•

.,

_ 

### ,i '" •R 

## a= nil
, Vm.--/9.1i Aff= -2,:o I I HJ,:, .„,,i; = , = 

# FIELD DATA SHEET

Moisture Recover Data: lmpinger 1 2 3 4 Desiccant Total Final wt., g 

### Initial wt., g ( ■ 

### 3 11/4)c, c› 41 P\ Difference j ( 7 /5 i •5 .1 ,., /kg Integrated Gas Sampling Data:

# EPA METHOD 4 E3ARR 1. ■ • ■ Project 

### ,A):41, s / 1 /1-1: - A `5 , 

### CM 5— SM 

## P 2, Pitat No. 

# 11- _ Op 

### t Sample Train Leak Rate (cfm) Sample Location 

### LS Meter y 

### (l e n 

## 4 4 6 Bar. Press., 

### 2.'S in Hg Pretest 

### 0.0 at 15 in Hg Date 1 

### 2.12.7.16

- F Test 2 

### - Run 

### 3 Orifice AH Posttest at 1 - in Hg Operators 

### VTA(..._ Eff. Probe Length ft Liner Type: El 

### Glass IV-S.S. El Other

Sample

Point . Sample

Time

AT . Meter Volume Vm, liters Meter @ H

. Iv. H20 Sample Vacuum,

in Hg Stack Sample Train Temperatures, °F ., . Oxygen Content, % Temp. Ts, °F Probe

. Filter - lmpinger Outlet Meter ' Inlet Meter Outlet ( 

## S - ) ( .S ( ' 5

. 511 ill 

# ' i l l ?

.

.... l'' 

# ' 77 

# A

- 

### G 5 - s 

### cot 

## CI 36 2„ Lc • /1 1- Zi

-- 0 2 s SI5 - • is.z., si 'Is i 3._.s 1 5 - i i 

## 1- 2 5'... Z r ( 

## V 9 7 3 3/ 5' I 3,

-- Sz 1;74 1 I 

## ‘ 1 - ) C1- / re. z s' 

## 1 '4 1 - . 3 / 3 2-3 $21..zt 3.4% I .. 

## 5-- 

# » , a 25

- 0 tr, 7, 2 r rtY.ri 3.36 — 

# i, r ,/ v ..z.s-4 1.5-4
._. 3 g 7 z 3c rzs. Gz 5..19 . , 

## I. )- 

## ( 1 i g . 2 S

- Q 2 f / r z.- 3-g 

## 7z. 

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### li ( it Z. 

### 5 - -° 1. 4 i i 

## f 1._ 537:4- S• VI 

## s - i. 11
- 1— 2 

### -"

. 5 - 2.. Y.) Y 

## Y r scq 6-, 0 S 3. li 1 I. c t VI 2c z .sz_ r2.. 1- ii 1-3 3 co 

## 3-(3. in- 119 I.'S - 

## HT
3- 

## C 

## sY4. (4.5" 7:7 , g ? , .5 - i 11- z :$' 2. yi S

- 51, 

## yy 

# z.-41 t 

# o 15 c II 4-



# - .

vm= Lis 6 7- sFr=

- Le

- 

### Mit 

## Mt

. t h. 

# - .r - -. • „ , '""tafigglaiiArr7

- . T

- rn= L......„.... „ 

# FIELD DATA SHEET

Moisture Recovery Data: Intinger 1 2• 3 4 Desiccant Total I Final wt., g 

# JO 0 1e3co Initial wt., g. hs 0 

# ALA toly Difference 

# iti Ni c?
..,.. I C 

### Integrated Gas Sampling Data: Box No. Leak Rate, cc/min Bag No. 02 Reading Bag Vol. 02 Analyzer No. at 15 in Hg

# Appendix C
Instrument Output

### Barr Engineering Co. DL Output Line 11 Waste Gas Stack - SV 104 Gaseous Pollutant Testing December 21, 2005 Northshore Mining Co. Slyer Bay, Minnesota Pellet Plant NShore_L11_NOx RECORD RN 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 TOA5 TIMESTAMP TS 12/21/2005 7:34 12121/2005 7:35 12/21/2005 7:36 12/21/2005 7:37 12/21/2005 7:38 12/21/2005 7:39 12/21/2005 7:40 12/21/2005 7:41 12/21/2005 7:42 12/21/2005 7:43 12/21/2005 7:44 12/21/2005 7:45 12/21/2005 7:46 12/21/2005 7:47 12/21/2005 7:48 12/21/2005 7:49 12/21/2005 7:50 12/21/2005 7:51 12/21/2005 7:52 12/21/2005 7:53 12/21/2005 7:54 12/21/2005 7:55 12/21/2005 7:56 12/21/2005 7:57 12/21/2005 7:58 12/21/2005 7:59 12/21/2005 8:00 12/21/2005 8:01 12/21/2005 8:02 12/21/2005 8:03 12/21/2005 8:04 12/21/2005 8:05 12/21/2005 8:06 12/21/2005 8:07 12/21/2005 8:08 12/21/2005 8:09 12/21/2005 8:10 12/21/2005 8:11 12/21/2005 8:12 12/21/2005 8:13 12/21/2005 8:14 12/21/2005 8:15 12/21/2005 8:16 12/21/2005 8:17 12/21/2005 8:18 12/21/2005 8:19 12/21/2005 8:20 12/21/2005 8:21 12/21/2005 8:22 12/21/2005 8:23 12/21/2005 8:24 12/21/2005 8:25 12/21/2005 8:26 12/21/2005 8:27 12/21/2005 8:28 12/21/2005 8:29 12/21/2005 8:30 12/21/2005 8:31 12/21/2005 8:32 12/21/2005 8:33 12/21/2005 8:34 - 12/21/2005 83

- $ 12/21/290,58: 3-6. 12/112ö05837 .12/21/2665

- 838: 12/21 /200509 . 12/21/2605 

## OP':

: 1

- 2/21'/200,5 8:41

12/21/2005 8.42;' 2/21/2605,6:4' NOx_Avg 02_Avg CO2_Avg PPM Percent Percent Comments -0.2 0.0 0.0 Analyzer Calibration -0.2 0.0 0.0 Analyzer Calibration -0.1 0.0 0.0 Analyzer Calibration 14.1 0.0 0.0 Analyzer Calibration 79.0 0.0 0.0 Analyzer Calibration 90.0 0.0 0.0 Analyzer Calibration 89.7 0.0 0.0 Analyzer Calibration 66.0 0.0 0.0 Analyzer Calibration 50.7 0.0 0.0 Analyzer Calibration 50.0 0.0 0.0 Analyzer Calibration 223 6.1 2.5 Analyzer Calibration 0.4 20.0 5.0 Analyzer Calibration 0.3 15,8 7.2 Analyzer Calibration 0.2 8.9 8.9 Analyzer Calibration 0.3 9.5 6.0 Analyzer Calibration 2.4 17.6 0.0 System Bias Check 9.1 3.2 -0.1 System Bias Check 2.7 0.2 -0.1 System Bias Check 0.4 0.1 0.0 System Bias Check 0.3 0.1 0.0 System Bias Check 0.2 0.0 0.0 System Bias Check 0.2 0.0 0.0 System Bias Check 0.1 0.0 0.0 System Bias Check 0.1 0.0 0.1 System Bias Check 15.5 0.1 0.1 System Bias Check 75.9 0.1 0.1 System Bias Check 87.9 0.0 0.1 System Bias Check 88.2 0.0 0.0 System Bias Check 87.8 0.0 0.0 System Bias Check 80.6 0.0 0.0 System Bias Check 55.0 0.0 -0.1 System Bias Check 49.4 0.0 -0.1 System Bias Check 49.6 0.0 0.0 System Bias Check 49.7 0.0 0.0 System Bias Check 49.0 0.0 0.0 System Bias Check 24.8 0.0 0.0 System Bias Check 2.1 0.0 0.0 System Bias Check 1.3 0.0 0.0 System Bias Check 1.7 0.0 0.0 System Bias Check 37.3 0.0 0.0 System Bias Check 86.6 0.0 0.0 System Bias Check 88.6 0.0 0.0 System Bias Check 67.2 0.5 0.6 System Bias Check 14.0 16.7 4.7 System Bias Check 5,2 19.6 4.9 System Bias Check 4.5 19.8 5.0 System Bias Check 4.1 19.9 _4.9 4 System Bias Check 4.1 15.5 7.1 System Bias Check 3.5 9.5 8.7 System Bias Check 3.0 8.9 8.8 System Bias Check 2.4 8.9 8.8 System Bias Check 2.1 . 8.9 8.8 System Bias Check 1.9 8.4 7.3 n Stack 2.0 2.1 0.7 n Stack 24.5 11.9 1.4 n Stack 82,0 16.8 1.6 n Stack 90.0 17.3 1.6 n Stack 88.9 17.3 1.6 n Stack 87.1 17.3 1.6 n Stack 87.1 17.3 1.6 n Stack 88.6 17.3 1.6 n Stack 89.3 . 17.2 Run 1 92.0 1

- 7.2 Run 1 , 92.1 117

. 2 , - 1

. 7 Run 1

., _ 93.3 17.2 1.7 Run 1 • - 95.0 - 17.1 1.7 , Run 1

98.7 17.1 1.7 Run 1 17.1 - 1.7 Run 1 - s .1 -17.2.. , Run 1 95.3 , 17.2 1.7 Run 1
Page 

### 1 of 5Barr Engineering Co. DL Output Line 11 Waste Gas Stack - SV 104 Gaseous Pollutant Testing December 21, 2005 Northshore Mining Co. Siver Bay, Minnesota Pellet Plant
TIMESTAMP RECORD NOx Avg 02_Avg CO2_Avg TS RN PPM Percent Percent 12/2112905. , ,,844_'),:. -, .''.7.0:_7 965 - '1'

. .172' .7'..*:"7 '77

. -:1

.

..;7

. 7

.7, ..7

. .. ...12/.2.11.4-01;4. 71 974 172 . 1:.7 : 12/2122.00

- $4340, . z 96:9: 2 17 ,

. , , . 12/91/2095 t

. 4777

. •:: • 73, • "97.7 • • 172; 1,7

_ • - 1 12/27005

. 848

. : 74 '-.

- ....:1009 . '::.:'.17-:1 - 17

- : : -,. ., , . . - 12/21/2005J349 75... ; ,; ., 102',5 , .,.'• 17..'1 : . ..1 ; .7 7

1 202!-_666 '6 , .68 ; _.101'

. . - 0 . 174 . . : .

.„ , , ' 1 :7...

: - .1 2/21/4900 , 8:51 T

. 77

. ..., •

. : . 102.g 

### : 1.7: , i.. , . 1.7 , L12i21/2905'852. : ..78:;

.. 1012 • ..12/21(2005.8:6.' 7 9 1.7 .:12/21/2005 854 .. .0.";.;; 10174 ,:.:: ..7`17

.. .1 1:7. - 7:12/2119005;8

. 55: .. 1 1 'lot 8 .:77: ' 11,1; .1..i7

. .7. : ....,_, , •. • ; 7

.. 19/21/2005.7856.... • 82 '109.9 7 .1

. 7.'1 ' 12/21/2005 8;67 1 ,.. .- 83 100,. ..1 ].- :. - 177.17,- 1:67 12/21/2005 8:58. ._ •s4. 100.2.. 17:1 ' 1i8 ,...

. . : 12/21/2005859.,7. • 85

. ...993 : 17.1 ' :7 1.P ".., . . 12/1

- 1.

- 20,0s::909:::, ' 8

. 6 .: 190.7. 17.1 1:8

. : . .. 12/91/96,05 = ::901. - 7 • : 100.6 17.1 7. 1.6:

. , - . .. .. 7,.. • : ,:,9 : ,:7;1 - , „.: 12/21/2005' .902,7 : 88 99 17 18 ', 719

. 191/2009:..903'7 .99.1 '17,1, : 1:6

: 12/2112005 9:04 .' -7.

- 790 • ' ; 96.4 717.2 : ...1.7

• 12/21/2005

. 905 :. 791" 7: 1: : : 95.1 : , 1.7.2 . . 1:7:
• :: 7

,.• :. 12/21/2005

. 906 ., 92 , ;',.95.27'. :. 17.2 7

. 17 ' 12/21/2005 9;07: 7' 7 ..96

. :

. 0 . ..17,1

- . ... I 12/21/2005908. 7 : 95,7 • .171 . ,...12/91/2005:909: , .. ..795,9 : i 171 : ......12/21/20059 10 96 9.8 , - . :17 2 :-

. 1 -- 12/2112005 911 :7'9811.: ,..:17.0... :712/21/2005.912

. .. :::99:4

. :17,0 : 12/21/2005913 99 '99:7i: 7 .170: : .: , ... 12/21/2005 6:14 100

- i: 1005 17.,0r.. 12/21/2005915 - • 101 n.' -1

- 00.8:.

. - ,i7ci 12/21/20059 16 :, 104

. :'

. 1021 ,- .173:1; ' :

. : ..: 12/21/.20059:17, . .7103

. ... 103,6"7
-. ... 7:. 17,o. 112/21/2905 9

. 16 •: . !

- 104 , ,103,S;LJ:

- 179

_ . .. , . : : 12/21/2005

. 919 . • :1p5"

. - ..10,..,3r_,' 17,07••

. 12/211200577920; :10$ . , 1016 :- , : 17.0 t 12/2112005921 ' 1,07::: .,, .,-.4000 , r, : : -170 " .12(211n05.'9,2 , :' _ 108

. ::-, I : ,100.9:, - : 17.0. .1212',Ii00593

- 10

- 9*.: :' . • :1

. 093

. . . . 171 ; 12/ 2 1/2005 924 10 '‘• .1

,. - 

## : ,, .. .., ;160., :, 17:1:-__ ,12q1 (200s 925 111 : ::-.. 190.7.:,.:. 7 171 .- 12/21/2005926 7

. 1.12. , 7: 100g .. :: ; 17:1.

., .. _. - . 12/2

. 1 /2005 927: 113 ; E:

. 96.:V 17.1 :-

. . 12/21 /9005 9

.. .28..:: 7...:•114,'::

. ::99

. :4.2.: .7. 7' .17. • 1

..7 ,12/21/2005 929 , • 

### 115 971 -•.• 171

12/21/2005930 !: 116 • : .171 12/21/2005931 . - 117 ' 96.1 .:.- . 171 ,

i i

. 1,21i20Q5 932

. 118 .7.996 .7:. , 7

. :
. -: :•17,. .,1 12/21/2005933 : . 119 -

- .97.:" .0=7 , 17.,1. 

### 127.1* , ./2

. _005r:54•-•' L : 120-::' , . 

### 97.1 ,:: :171.: Average Run 1 98.5 17.1

12/21/2005 9:35 121 96.6 17.1 1.8 System Bias Check 12/21/2005 9:36 122 96.6 17.2 1.8 System Bias Check 12/21/2005 9:37 123 96.9 16.6 1.6 System Bias Check Reporgram Datalogger to adjust NOx analyzer scale to 0-1,000 ppm. 0 15.1 0.1 0.1 System Bias Check 2.6 0.1 0.1 System Bias Check 1 2 7 :

- .1.4.

- . - 0.1 011 System Bias Check 3 4.0 0.1 0.1 System Bias Check 4 9.6 0.1 0.1 System Bias Check 5 38.9 0.0 0.1 System Bias Check 6 78.9 0.0 0.1 System Bias Check 7 80.8 0.0 0.1 System Bias Check 8 83.8 0.0 0.1 System Bias Check 9 851 0.0 0.1 System Bias Check 10 86.4 0.0 0.0 System Bias Check 11 86.3 0.0 0.0 System Bias Check 12 85.9 0,0 0.0 System Bias Check 13 85.8 0.1 0.1 System Bias Check Comments

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12/21/2005 9:39 12/21/2005 9:40 12/21/2005 9:41 12/21/2005 9:42 12/21/2005 9:43 12/21/2005 9:44 12/21/2005 9:45 12/21/2005 9:46 12/21/2005 9:47 12/21/2005 9:48 12/21/2005 9:49 12/21/2005 9:50 12/21/2005 9:51 12/21/2005 9:52

Page 2 of 5

### Barr Engineering Co. DL Output Northshore Mining Co. Slyer Bay, Minnesota Pellet Plant Line 11 Waste Gas Stack - SV 104 Gaseous Pollutant Testing December 21, 2005
TIMESTAMP RECORD NOx_Avg 02_Avg CO2_Avg TS RN PPM Percent Percent Comments 12/21/2005 9:53 14 126.0 0.2 0.0 System Bias Check 12/21/2005 9:54 . 15 225.7 0.1 0.0 System Bias Check 12/21/2005 9:55 16 242.8 0.0 0.0 System Bias Check 12/21/2005 9:56 17 251.3 0.0 0.0 System Bias Check 12/21/2005 9:57 18 250.9 0,0 0.0 System Bias Check 12/21/2005 9:58 19 249.4 0.0 0.0 System Bias Check 12/21/2005 9:59 20 249.2 0.0 0.0 System Bias Check 12/21/2005 10:00 21 248.3 0.0 0.0 System Bias Check 12/21/2005 10:01 22 212.8 0.0 0.0 System Bias Check 12/21/2005 10:02 23 107.3 0.0 0.0 System Bias Check 12/21/2005 10:03 24 89.9 0.0 0.0 System Bias Check 12/21/2005 10:04 25 89.8 0.0 0.0 System Bias Check 12/21/2005 10:05 26 84.6 5.2 2.5 System Bias Check 12/21/2005 10:06 27 29.1 18.9 5.0 System Bias Check 12/21/2005 10:07 28 3.2 19.8 5.1 System Bias Check 12/21/2005 10:08 29 2.3 19.8 5.1 System Bias Check 12/21/2005 10:09 30 2.5 19.9 5.1 System Bias Check 12/21/2005 10:10 31 2.8 19.9 4.8 System Bias Check 12/21/2005 10:11 32 28.9 18.8 2.0 In Stack 12/21/2005 10:12 33 85.4 17.3 1.7 In Stack 12/21/2005 10:13 34 93.0 17.2 1.7 In Stack 12/21/2005 10:14 35 93.9 17,2 1.7 In Stack 12/21/200510:15 .:.,: 36 . 94.2 7 „ 17,1 1,7 : ,RUn 2 .' 12/21/200510:16 ' . 37 94.5 17.1 1.7 *Run 2 12i21/200.16:17 38 . 94,5 17.1 1.7 Run 2 . 12/21/2005'10:18 , 39, ' 98.0 17.1 1,7 Run 2 :.:.12/2

- 1/2000f10:19 '.- 4

. 0' 95.0: .

. : 17.1 ' " 1.7 Run 2 .

• :

.. 12/21/200510:20.:::

. 95.4 17.1 11 , ... Run

. 2 12/21/20t*0:21 ,.' :94A ':' : 17.2H

. 1..r "Run' 2

_ . , .-,,. . ..,: • 12/21/200,510:22

. ' 00:0 : : I 17.1'

. 

### 1' .7 . .Run 2 

### 12/21/200516:23: 95:9' : 17.1 . 1.7 : , Run 2 1 2 /21/200510:24 '45 . , , :95,3 

### 17.1

.

_ : 1.7-

45 

### _11.4.i,

- 2•

- • ,‘ = ;124'1/4.000;5::: : , 40 '.

- -.11.±7.,._ 

### , 7Run 2' ,' .
„,i , .,*

- 1

-

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### , 12/21/2005 10:26


### „ 47 ..- P. ' 12/21/2005 10:27 ' ''P9§....2 1'. 

### 17A

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### :: - 1'7:1 17 RUn'2 

### ; - 121202005,*d6 49: : - 7195:6 3 - 

### , ... __ „. : 17:1 1 * * Run 2 '• 12/21/2005'.10:29.:, 

### 60;

. 97,1 17:1 "1.7 ; • ii.iri 2 ' .12/21/.20.0510o: 

### : §i 96:0 17.1 , 1.7 Run '2 12/21/2005-10:31 52 95:2 ' 17.1 1.7 Run 2 • 12/21/208102, 53 . 04,5 ., 

### 17,1 , 1,7 Run 2 " 12/21/2005 10:33 : 54 95.6 

### 17.1 17,1 

### 1.7 1.7 Run '2 12/21/2005 18:34 55 95.4 Ruh 2

. 

### 12/21/200510:35 i: 55 95,0 

### 17.1 • 1,7 Run 2

- 

### 12/21/200510:36 ' 57 95.3 : 17:1: 1.7 : Riih: 2 '

• : 12/211200540:37 69 : 98.2 17.1' 1.7 kun 2

. ,12/21/26

. 85A08 „: 59. .. ‘: 97.0 17.0 1.7 Run 2 12/21

. /

. 2005:1009;, 60 ' 

### p8.4' 17.0 1.7 . Run 

### 2 : 12 n /21/2905.71d:40 ' -91 99.1 17,0 1.8 Run 2 .12/21/2805

- ,1 0:441, , , : 62 100.0 17.0 1.7 Run

. - 2 .,1/21/2000J1942,.-: .. 63 

### 99:0 17:0' 1.7'. ,Run 2 . : 12/21/2

. 005101

- :,0,..: . '64 :

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### 2 * . 12/21/2051 0j44 65

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12/2112006,:10.:49;; : 

### lb 98.2 1.7. Run, 2



### - 12/21/2005 10:50. .71r. ; ' . 

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- - 7_ 12/21/260510:54i 75 : • 101.5: ' 17. : 1, :. 1.7 ROO2 - 12/21/2065=A 0:55 . : - 76 ''..: : '.9p:a :17.1 :-. ' RIO: 2 •
_ . , ,. 7: 12/217,2005 ;10:56 777; ::: 99k6

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### 78 ' ' ' 100.3 ' :7 17:1 -: 1.7 RUn 2 ' 12121/2005,E . 5 , 79 : . 9,,8

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### ., : 1 2/21/2065:,:11:01, 82 3 101,0 17.1 . 1,7 ' Run 2 -• 12/21/2066.j : 1:02'

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### 12/21/2005'11 :63 - 84 : : 99.2 17.1 1.7 Run 2


### Page 3 of 5Northshore Mining Co. Siver Bay, Minnesota Pellet Plant 

### Barr Engineering Co. DL Output Line 11 Waste Gas Stack - SV 

### 104 Gaseous Pollutant Testing December 21, 2005
TIMESTAMP RECORD NOx Avg 02_Avg CO2_Avg TS RN PPM Percent Percent Comments 12/21/2005 11X.1,4 85 '98.6..._ 17



### , Ran .2, : ' , - . ' 

### 12/21/2005 1105 86 97,7 -:, ' ' 172

. Run 2 _

12/21/20051106 , 

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, , 12/21/2005 11:0/, '

. 88 • .94:0 • 17,2 1

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. 173: • 

### 1.s Run 2 ',.:. 

### 1z/21/20051100 .bi , .9"1:.'i-:'
, 1 7:• 3 1.6 Run 2 12/21/2005 1111 .' .93i: 17,3

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. :6 Run 2 .. 12/21120051112 93 924 .. 17.3 • 1.6 .. Run 2

„ . „ , 1 g/21/2005 1113 94 899; 17 3 . 1 . 6 : Run 2

, . ' '112/21/20051114 95 91,6: - ' 17:3:: 1:6' , ' 'Run.2 .•

Average Run 2 96.5 17.1 1.7 Average Run 2
12/21/2005 11:15 96 91.6 17.2 12/21/2005 11:16 97 91,3 17.2 12/21/2005 11:17 98 87.2 16.9 12/21/2005 11:18 99 38.5 3.5 12/21/2005 11:19 100 0.5 0.5 12/21/2005 11:20 101 -0.6 0.1 12/21/2005 11:21 102 -0.1 0.1 12/21/2005 11:22 103 -0.3 0.1 12/21/2005 11:23 104 17.3 0.1 12/21/2005 11:24 105 76,0 0.1 12/21/2005 11:25 106 86.5 0.1 12/21/2005 11:26 107 85.9 0.1 12/21/2005 11:27 108 86.4 0.0 12/21/2005 11:28 109 82.5 5.4 12/21/2005 11:29 110 28.5 19.4 12/21/2005 11:30 111 0.8 19.8 12/21/2005 11:31 112 0.7 19.9 12/21/2005 11:32 113 1.5 19.8 12/21/2005 11:33 114 44.6 18.3 12/21/2005 11:34 115 91.2 17.2 '12/21/2005:11:35 , 116 94.2 - 17,2 - 12/211200 111-35

. 

### . 117 ;94.2 17,2 • 12121120O5_11:37 1.18 95.5 17.2 ::.12/2112005 7 1138 ..., 119 , 96,5,' , 17.2 ' 12/21/20051139 - :120 • '.' - 95 2'.:',.: 1 7

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. 12/2 112005;41 :43.:, 124 , 95:5: : ; 17;2.:

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### .,/,t,1.1,41.1‘;45 126 : 97.4 - • ,7- .41,.1


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- 241/26061.1:: • 4

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### :1,20 . :'96.1l: 171 1.7 12/21/20051149 

### .. : 150 ,, 95,3 . 17.1 1,7' 12/21/2005 

### 1150 131 : 96,1 17.1., 1,7 : ' 12/21/20051151 132 99

. :6 . 17.1. 1.7 12/2:1/2605 11:52 133 100,4



### . 17.1 1.7 • ' 12/21/2'095 11:53-, .:- 134 101,5 .. 17.1 .1.7

1

. 2121/2605:1,1:54 :: 135 1 00

. 5 17.0 _ 1:7 12/21/200511 : 1 55 :"' -- , 136 : : 1023 ' 170 - .-, 1.7

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### Page 4 of 5. - 164 •
.•

. 165 • ••• Barr Engineering Co. DL Output Northshore Mining Co. Siver Bay, Minnesota Pellet Plant Line 11 Waste Gas Stack - SV 104 Gaseous Pollutant Testing December 21, 2005 CO2_Avg Percent

1 .7 1.7 1.7 1.7 RECORD RN
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### 1.8 12/21/2005 12:42 183 25.9 12/21/2005 12:43 184 81.6 12/21/2005 12:44 185 88.8 12/21/2005 12:45 186 88,8 12/21/2005 12:46 187 88.6 12/21/2005 12:47 188 130.0 12/21/2005 12:48 189 233.8 12/21/2005 12:49 190 248.8 12/21/2005 12:50 191 247.2 12/21/2005 12:51 192 250.4 12/21/2005 12:52 193 250.0 12/21/2005 12:53 194 176.5 12/21/2005 12:54 195 23.0 12/21/2005 12:55 196 2.8 12/21/2005 12:56 197 2.5 12/21/2005 12:57 198 2.2 12/21/2005 12:58 199 2.0 17.2 1.7 17.2 1.7 11.6 1.6 1.0 0.0 0.1 0.0 0.1 0.0 

### 0.1 0.0 0.1 0,0 0.1 0.0 0.1 0.0 0.1 0.0 0.1 0.0 0.1 0.0 0.1 0.0 0.1 0.0 0,0 0.0 0.0 0,0 0.0 0.0 8.0 2.9 19.6 5.0 19.9 5.0 19.9 5.0 19.5 4.5 3.7 0,4 Systme Bias Check Systme Bias Check Systme Bias Check Systme Bias Check Systme Bias Check Systme Bias Check Systme Bias Check Systme Bias Check Systme Bias Check Systme Bias Check Systme Bias Check Systme Bias Check Systme Bias Check Systme Bias Check Systme Bias Check Systme Bias Check Systme Bias Check Systme Bias Check Systme Bias Check Systme Bias Check Systme Bias Check Systme Bias Check Systme Bias Check End Testing

Page 5 of 5Analyte Chart Pen Color Range Cal Gas Cylinder Number Value NOx Red 0-1,000 PPM Zero CC12629 0.0 Mid CC74110 50.3 High CC12639 90.5 Upper CA03145 251.6 02 Green 0-25% Zero CC12610 0.0 Mid CC376 8.9 High CC40094 20.0 CO2 Blue 0-20% Zero CC12610 0.0 Mid CC40094 5.0 High CC376 8.9 Chart Speed 20 cm/hr Technician Pete Rossmiller Barr Engineering


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Avg CO2_Avg Percent

Avg 12/22/2005 7:01 41.9 0.0 0.0 12/22/2005 7:02 33.7 0.0 0.0 12/22/2005 7:03 25.2 0.0 0.0 12/22/2005 7:04 1.0 0.0 0.0 12/22/2005 7:05 0.1 0.0 0.0 12/22/2005 7:06 8.7 0.4 0.0 12/22/2005 7:07 79.4 0.0 0.0 12/22/2005 7:08 91.7 0.0 0.0 12/22/2005 7:09 88.9 0.0 0.0 12/22/2005 7:10 64,4 0,0 0.0 12/22/2005 7:11 60.9 - 0.0 -0.1 12/2212005 7:12 49.5 0.0 -0.1 12/22/2005 7:13 33.7 0.0 0.0 12/22/20057:14 23.0 0.0 0.0 12/22/2005 7:15 2.4 0.0 0.0 12/22/2005 7:16 22.5 6.0 2.6 12/22/2005 7:17 6.6 20.0 5.1 12/22/2005 7:18 0.0 20.0 5.0 12/22/2005 7:19 -0.1 16.1 7.0 12/22/2005 7:20 -0.5 8.9 8.8 12/22/2005 7:21 -0.9 8.9 8,8 12/22/20057:22 -1.0 8.9 8.9 12/22/2005 7:23 -0.6 9.3 6.7 12/22/2005 7:24 1.8 18.9 0.2 12/22/2005 7:25 2.9 7.5 4.8 12/22/2005 7:26 0,8 7.9 7.6 12/22/2005 7:27 0.1 2.4 0.9 12/22/2005 7:28 0,3 0.3 0.2 12/22/2005 7:29 0.5 0.1 0.0 12/22/2005 7:30 0,4 0.1 0.0 12/22/2005 7:31 -0.1

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Analyzer Calibration Analyzer Calibration Analyzer Calibration Analyzer Calibration Analyzer Calibration Analyzer Calibration Analyzer Calibration Analyzer Calibration Analyzer Calibration Analyzer Calibration Analyzer Calibration Analyzer Calibration Analyzer Calibration Analyzer Calibration Analyzer Calibration Analyzer Calibration Analyzer Calibration Analyzer Calibration Analyzer Calibration Analyzer Calibration Analyzer Calibration Analyzer Calibration Analyzer Calibration System Bias Check System Bias Check System Bias Check System Bias Check System Bias Check System Bias Check System Bias Check System Bias Check System Bias Check System Bias Check System Bias Check System Bias Check System Bias Check System Bias Check System Bias Check System Bias Check System Bias Check System Bias Check System Bias Check System Bias Check System Bias Check System Bias Check System Bias Check System Bias Check System Bias Check System Bias Check System Bias Check System Bias Check System Bias Check System Bias Check System Bias Check In Stack In Stack In Stack In Stack In Stack Run 1 Run 1 Run 1 Ruh 1 • ' Run 1 „ Run 1 , - Rt.in't . .RYP 1 '



### .. Run 1' .Run ,1 . Run 1'


### Page 1 of 5

### Northshore Mining Co. Line 6 Waste Gas Stack - SV621 Gaseous Pollutant Testing Barr Engineering Co. Silver Bay, Minnesota December 22, 2005 DL Output Pellet Plant

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### Page 2 of 5Northshore Mining Co. Line 6 Waste Gas Stack - SV621 Gaseous Pollutant Testing Barr Engineering Co. Silver Bay, Minnesota December 22, 2005 DL Output Pellet Plant
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Page 3 of 5Northshore Mining Co. Silver Bay, Minnesota Pellet Plant
TIMESTAMP NOx_Avg TS PPM 12/22/2005 10:29 16.5 12/22/2005 10:30 1.7 12/22/2005 10:31 -0.6 12/22/2005 10:32 -0.7 12/22/2005 10:33 4.1 12/22/2005 10:34 21.0 .12/22/2005'10:35 • • 

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Page 4 of 5Northshore Mining Co. Line 6 Waste Gas Stack - SV621 Gaseous Pollutant Testing Barr Engineering Co. Silver Bay, Minnesota December 22, 2005 DL Output Pellet Plant
TIMESTAMP NOx_Avg 02_Avg CO2_Avg TS PPM Percent Percent Comments 12/22/2005 11:38 10.7 1.5 0.1 System Bias Check 12/22/2005 11:39 0.4 0.2 0.0 System Bias Check 12/22/2005 11:40 -0.1 0.1 0 0

. , System Bias Check 12/22/2005 11:41 -0.1 0.1 0.0 System Bias Check 12/22/2005 11:42 2.8 0.1 0.0 System Bias Check 12/22/2005 11:43 18,1 0.1 0.0 System Bias Check 12/22/2005 11:44 2 3.5 0.1 0.0 System Bias Check 12/22/2005 11:45 23.7 0.1 0.0 System Bias Check 12/22/2005 11:46 19,9 10.7 3.6 System Bias Check 12/22/2005 11:47 3.8 19.7 5.0 System Bias Check 12/22/2005 11:48 -0.1 19.9 5.0 System Bias Check 12/22/2005 11:49 -0.1 19.9 5.0 System Bias Check 12/22/2005 11:50 -0.2 19.9 5.0 System Bias Check 12/22/2005 11:51 -0.3 19.4 4.4 System Bias Check 12/22/2005 11:52 -0.4 3.5 0.4 System Response Check 12/22/2005 11:53 -0.3 0.3 0.1 System Response Check 12/22/2005 11:54 -0.3 0.1 0.1 System Response Check 12/22/2005 11:55 0.3 0.1 0.0 System Response Check 12/22/2005 11:56 43.0 0.1 0.0 System Response Check 12/22/2005 11:57 86.7 0.1 0.0 System Response Check 12/22/2005 11:58 88.5 0.0 0.0 System Response Check 12/22/2005 11:59 88.8 0.0 0.0 System Response Check 12/22/2005 12:00 85.5 0.1 0.1 System Response Check 12/22/2005 12:01 30.8 0.1 0.0 System Response Check 12/22/2005 12:02 0.5 0.0 0,0 System Response Check 12/22/2005 12:03 0.0 0.0 0.0 System Response Check 12/22/2005 12:04 28.6 0.0 0.0 System Response Check 12/22/2005 12:05 84.3 0.0 0.0 System Response Check 12/22/2005 12:06 88.8 0.0 0.0 System Response Check 12/22/2005 12:07 88.8 0.0 0.0 System Response Check 12/22/2005 12:08 87.6 0.0 0.0 System Response Check 12/22/2005 12:09 64.6 0.1 0.0 System Bias Check 12/22/2005 12:10 49.4 0.0 0.0 System Bias Check 12/22/2005 12:11 49.3 , 0.0 0.0 System Bias Check 12/22/2005 12:12 49.1 0.0 0.0 System Bias Check 12/22/2005 12:13 43.7 0.0 0.0 System Bias Check 12/22/2005 12:14 10.5 0.0 0.0 End Testing

Page 5 

### of 5Analyte Chart Pen Color Range Cal Gas Cylinder Number Value
NOx Red 0-100 PPM Zero CC12629 0.0 Mid CC74046 24.8 High CC74110 50.3 Upper CC12639 90.5
02 Green 0-25% Zero CC12610 0.0 Mid CC376 8.9 High CC40094 20.0
CO2 Blue 0-20% Zero CC12610 0.0 Mid CC40094 5.0 High CC376 8.9 Chart Speed 20 cm/hr Technician Pete Rossmiller Barr Engineering



# December 22, 2005 Line 6 (SV261) NOx Emissicns Testing Northshore Mining Silver Bay, Minnesota— 1
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# Appendix D

Calibration DataI Average: I 61 1 2 3 61 62 60 

### EPA METHOD 3A ANALYZER CALIBRATION 

# BARR
Project Northshore Mining Sample Location Line 11 (SV104) - NOx Emission Inventory Testing Date 12/21/2005 Operators P. Rossmiller
Analyzer Make / Model / SN Cal. Anal. Model 200 Analyzer 0 2 Range (span), °A: 25 Analyzer CO 2 Range (span), %: 20 Stripchart Speed (units): 20 cm/hr

ANALYZER CALIBRATION DATA Note: Difference must be less than +/- 2 percent of span Cylinder Serial No. Cert. PPM Zero Gas CC12610 0.0 0 2 Mid-range - CC376 8.9 0 2 High-range CC40094 20.0 CO 2 Mid-range CC40094 5.0 CO 2 High-range CC376 8.9

0 2
Test Runs : Test 1 R1

Zero Gas Cylinder Value,

% Analyzer Calibration Response, % Absolute Difference % Difference, Percent of

Span 0.0 0.0 0.0 0.00% Mid-range: 8.9 8.9 0.1 0.20% High-range: 20.0 20.0 0.0 0.08%

CO 2
Test Runs : Test 1 R1 Cylinder Value,

% Analyzer Calibration Response, % Absolute Difference % Difference, Percent of

Span Zero Gas 0.0 0.0 0.0 0.00% Mid-range: 5.0 5.0 0.0 0.10% High-range: 8.9 8.9 0.0 0.15%

PRETEST RESPONSE TIME Note: Time to register 95% stepchange with high level gas. 

# I Response

Time (sec)

SYSTEM CALIBRATION BIAS AND DRIFT DATA: Note: System Cal bias cannot exceed +/- 5 percent of span. Drift cannot exceed +/- 3 percent of span

TEST RUN 1 Initial Values Final Values Analyzer Cal Response, % System Cal Response, % System Cal Cal. Bias % of Span .System Cal Response, ok System Cal Cal, Bias % of Span Drift, Percent of

span Zero Gas 02 0.0 0.0 0.00% 0.0 0.00% 0.00% Upscale Gas 02 20.0 19.9 -0.40% 19.9 -0.40% 0.00%. Zero Gas CO2 0.0 0.0 0.00% 0.0 0.00% 0.00% Upscale Gas CO 2 5.0 5.0 0.00% 5.1 0.50% -0.50%

TEST RUN 2 Zero Gas 02 0.0 0.0 0.00% 0.1 0.40% -0.40% Upscale Gas 0 2 20.0 19.9 -0.40% 19.9 -0.40% 0.00% Zero Gas CO2 0.0 0.0 0.00% 0.0 0.00% 0.00% Upscale Gas CO 2 5.0 5.1 0.50% 5.0 0.00% 0.50%

TEST RUN 3 Zero Gas 0 2 0.0 0.1 0.40% 0.1 0.40% 0.00% Upscale Gas 02 20.0 19.9 -0.40% 19.9 -0.40% 0.00% Zero Gas CO2 0.0 0.0 0.00% 0.0 0.00% 0.00% Upscale Gas CO2 5.0 5.0 0.00% 5.0 0.00% 0.00%
System Calibration Bias = [(System Cal. Response - Analyzer Cal. Response) / Span] x 100 Drift = [(Final System Cal. Response - Initial System Cal Response) / Span] x 100

### Analyzer Calibration Response, PPM -0.1 50.4 90.5 251.6 Absolute Difference PPM Difference, Percent of Span 0.1 0.01% 0.1 0.01% 0.0 0.00% 0.0 0.00% 

## EPA METHOD 7E - Nox ANALYZER CALIBRATION 

# BARR Project Northshore Mining 

## Sample Loc. Line 11 (SV104) - NOx 

## Emission Inventory Testing Date 12/21/2005 

## Operators P. Rossmiller Cylinder Serial No. Cert. PPM CC12629 0 

## Analyzer Make / Mod. / SN API Model 200EH Analyzer Range (span), PPM: 

## 1000 

## Stripchart Speed (units): 20 cm/hr Zero Gas Mid-range High-range Upper-range CC74110 50.3 CC12639 90.5 CA03145 251.6



## ANALYZER CALIBRATION DATA Note: Difference must be less than +/- 2 percent of span

Test Runs : Test 1 R1

Zero Gas 

## Cylinder Value,

PPM

0 

### Mid-range 50.3 High-range: 90.5 Upper-range: 251.6

PRETEST RESPONSE TIME Note: Time to register 95% stepchange with high level gas.
I Average: I 77 

# I Response

Time (sec) 2 3 75 78 78



## SYSTEM CALIBRATION BIAS AND DRIFT DATA: Note: System Cal bias cannot exceed +/- 5 percent of span. Drift cannot exceed +/- 3 percent of span

TEST RUN 1 Initial Values Final Values Analyzer Cal

Response, PPM System Cal Response, PPM System Cal Cal. Bias % of Span System Cal Response, PPM System Cal Cal. Bias % of Span Drift, Percent of span Zero Gas -0.1 0.1 0.02% -0.8 -0.07% -0.09% Upscale Gas 90.5 88.9 -0.16% 86.1 -0.44% -0.28%

TEST RUN 2 Zero Gas -0.1 -0.8 -0.07% -0.5 -0.04% 0.03% Upscale Gas 90.5 86.1 -0.44% 86.2 -0.43% 0.01%

TEST RUN 3 Zero Gas -0.1 -0.5 -0.04% 2.7 0.28% 0.32% Upscale Gas 90.5 86.2 -0.43% 89.3 -0.12% 0.31%

System Calibration Bias = [(System Cal. Response - Analyzer Cal. Response) / Span] x 100
Drift = [(Final System Cal. Response - Initial System Cal Response) / Span] x 100

### ANALYZER CALIBRATION EPA METHOD 3A

BR immissommi Project Northshore Mining Sample Location Line 6 (SV261) - NOx Emission Inventory Testing
Cylinder Serial No. Cert. PPM Zero Gas CC12610 0.0 0 2 Mid-range CC376 8.9 0 2 High-range CC40094 20.0 CO 2 Mid-range CC40094 5,0 CO 2 High-range CC376 8.9 

### ANALYZER CALIBRATION DATA Note: Difference must be less than +/- 2 percent of span

02 Test Runs : Test 1 R1

Zero Gas Cylinder Value,

% Analyzer Calibration Response, % Absolute Difference % Difference, Percent of

Span 0,0 0.0 0.0 0.00% Mid-range: - 8.9 8.9 0.1 0.20% High-range: 20.0 20.0 0.0 0.08%

CO 2
Test Runs : Test 1 R1 Cylinder Value,

% Analyzer Calibration Response, % Absolute Difference % Difference, Percent of

Span
Zero Gas 0.0 0.0 0.0 0.00% Mid-range: 5.0 5.0 0.0 0.10% High-range: 8.9 8.9 0.0 0.15%

PRETEST RESPONSE TIME Note: Time to register 95% s epchange with high level gas.
I Response 1 2 3 I Time (sec) 77 76 75 I Average: I 76



### SYSTEM CALIBRATION BIAS AND DRIFT DATA: Note: System Cal bias cannot exceed +/- 5 percent of span. Drift cannot exceed +/- 3 percent of span

TEST RUN 1 Initial Values Final Values Analyzer Cal

Response, % System Cal Response, % System Cal Cal. Bias % of Span System Cal Response, ok System Cal Cal, Bias % of Span Drift, Percent of

span Zero Gas 02 0,0 0.1 0.40% 0.0 0,00% 0.40% Upscale Gas 0 2 20.0 19.9 -0.40% 20.0 0.00% -0.40%.
Zero Gas CO2 0.0 0.0 0.00% 0.0 0.00% 0.00% Upscale Gas CO2 5.0 4.9 -0.50% 5.0 0.00% -0.50%

TEST RUN 2 Zero Gas 02 0.0 0.0 0,00% 0.0 0.00% 0.00% Upscale Gas 02 20.0 20.0 0.00% 19.9 -0.40% 0.40%
Zero Gas CO2 0.0 0.0 0.00% 0.0 0.00% 0.00% Upscale Gas CO2 5.0 5.0 0.00% 5.0 0.00% 0.00%

TEST RUN 3 Zero Gas 02 0.0 0.0 0.00% 0.1 0.40% -0.40% Upscale Gas 02 20.0 19.9 -0.40% 19.9 -0.40% 0.00%
Zero Gas CO2 0.0 0.0 0.00% 0.0 0.00% 0.00% Upscale Gas CO 2 5,0 5.0 0.00% 5.0 0.00% 0.00%
System Calibration Bias = [(System Cal. Response - Analyzer Cal. Response) / Span] x 100 Drift = [(Final System Cal. Response - Initial System Cal Response) / Span] x 100 Date 12/22/2005 Operators P. Rossmiller
Analyzer Make / Model / SN Cal. Anal. Model 200 Analyzer 0 2 Range (span), %: 25 Analyzer CO 2 Range (span), %: 20 Stripchart Speed (units): 20 cm/hr

## EPA METHOD 7E - Nox ANALYZER CALIBRATION 

# BARR Project Northshore Mining Sample Loc. Line 6 (SV261) - NOx Emission Inventory Testing Date 12/22/2005 Operators P. Rossmiller Cylinder Serial No. Cert. PPM 

## Analyzer Make / Mod. / SN API Model 200EH Zero Gas CC12629 0 Analyzer Range (span), PPM: 

## 100 Mid-range CC74046 24.81 

## Stripchart Speed (units): 20 cm/hr High-range CC74110 50.3 Upper-range CC12639 90.5


## ANALYZER CALIBRATION DATA Note: Difference must be less than +/- 2 percent of span

Test Runs : Test 1 R1

Zero Gas 

## Cylinder Value,

PPM Analyzer. Calibration Response, PPM Absolute Difference PPM Difference, Percent of Span 0 -0.1 0.1 0.10% Mid-range 24.8 23.5 1.3 1.31% High-range: 50.3 50.2 0.1 0.10% Upper-range: 90.5 90.5 0.0 0.00%

PRETEST RESPONSE TIME Note: Time to register 95% stepchange with high level gas.
Response 1 2 3 I Average: I Time (sec) 89 94 92 I 92 I



## SYSTEM CALIBRATION BIAS AND DRIFT DATA: Note: System Cal bias cannot exceed +/- 5 percent of span. Drift cannot exceed +/- 3 percent of span

TEST RUN 1 Initial Values Final Values Analyzer Cal

Response, PPM System Cal Response,

' PPM System Cal Cal. Bias % of Span System Cal Response, PPM System Cal Cal. Bias % of Span Drift, Percent of span Zero Gas -0.1 -0.1 0.00% -0.4 -0.30% -0.30% Upscale Gas 23.5 21.9 -1.60% 22.8 -0.70% 0.90%

TEST RUN 2 Zero Gas -0.1 -0.4 -0.30% 0.2 0.30% 0.60% Upscale Gas 22.8 22.8 0.00% 23.5 0.70% 0.70%

TEST RUN 3 Zero Gas -0.1 0.2 0.30% -0.1 0.00% -0.30% Upscale Gas 22.8 23.5 0.70% 23.5 0.70% 0.00%
System Calibration Bias = [(System Cal. Response - Analyzer Cal. Response) / Span] x 100
Drift = [(Final System Cal. Response - Initial System Cal Response) / Span] x 100

# THERMOCOUPLE CALI RATION

THERMOCOUPLE ID T

- 

## 39
Cal Date: 9/30/2005 

## Handheld 

# BARR

THERMOCOUPLE CALIBRATION

—0— Calibration Curve - Unit Under Test — Upper Limit of Calibration — Lower Limit of Calibration —Extrapolated Calibration Curve

500 600



### REFERENCE TEMPERATURE, deg.R 

### THERMOCOUPLE ID 

### T - 39 Regression R Squared = 0.999996 

## CALIBRATION TECHNICIAN: CCL

REFERENCE STANDARDS CAL. DATE LABORATORY NIST TRACEABILITY

Hart Scientific 9103-A s/n Al B289 12/11/2003 - Northern Balance & A3717010 & A3205006 Hart Scientific 9140 s/n Al B086 12/11/2003 Scale A3717010 & A3205006 

## Temperature Calibraion Points Reference Deg F (To) Probe Temp (deg F) Reference Temp (deg R) deg F + 460 Probe Temp (deg R), deg F + 460 Difference (degrees) % Diff Abs. T Is difference less than 1.5% at all measured points? 

## 20 70 150
20 69.9 149.9 19 69 149 480 529.9 609.9 479 529 609

1 0.9 0.9 0.2% 0.2% 0.1%

YES YES YES

Are extrapolated limits less than 1.5%? YES FAHRENHEIT CALIBRATION RANGE ,....-20

. ;?0 -4-200-LSD If not acceptable, describe corrective action: Technician signiture: 

# e. QA signiture:Media 150 70 20



# 61 ,0
) 

# 141.0 Probe Temp (deg F) 

## O Std Used Reference Deg F (To) Reference Corr Temp (deg R) deg F + 460 

# 61174:1 19q1 )6 , 0

Probe Temp (deg k), deg F + 460 Difference (degrees) % Diff Abs. T (Renkin) W 

## THERMOCOUPLE CALIBRATION Engineering Company

Thermocouple Number Date: e f

- )6 -0 

# 5.
Technician: 1_-

Diff. less than 1.5% at all 

### points. Graph Attached - Extrapolated Range with

. Diff_ <= 1.5% ( Yes / No) . (Yes/No)

to

• Description of the thermocouple's-function:

If not acceptable, describe corrective procedures undertaken:

• 

# b•?(-)}-1-j imeJ—0— Calibration Curve - Unit Under Test — Upper Limit of Calibration — Lower Limit of Calibration —Extrapolated Calibration Curve 

# THERMOCOUPLE CALIBRATION

THERMOCOUPLE ID T -34 Regression R Squared = 0.999992 700

400 400 500 600 700 

### REFERENCE TEMPERATURE, deg.R 

# THERMOCOUPLE CALIBRATION 

# BARR
-A-TOPM:CAZIO

Cal Date: 

## THERMOCOUPLE ID T - 34 9130/2005 

## Handheld CALIBRATION TECHNICIAN: CCL

REFERENCE STANDARDS

Hart Scientific 9103-A sin Al B289 Hart Scientific 9140 s/n Al B086 CAL. DATE
12/11/2003 12/11/2003 LABORATORY NIST TRACEABILITY

Northern Balance & A3717010 & A3205006 Scale A3717010 & A3205006 

## Temperature Calibraion Points 20 70 150 Reference Deg F (To) 20 69.9 149.9 Probe Temp (deg F) 19 69 150 

### Reference Temp (deg R) deg F + 460 480 529.9 609.9 Probe Temp (deg R), deg F + 460 479 529 610 Difference (degrees) 1 0.9

. -0.1 % Diff Abs. T 0.2% 02% 0.0% Is difference less than 1.5% at all measured points? YES YES YES

Are extrapolated limits less than 1.5%? YES FAHRENHEIT CALIBRATION RANGE 

### 4-20°0 - 1So

QA signiture: 

## trvoz'A -- If not acceptable, describe corrective action: Technician signiture: 

## 04 C.

### Engineering Company 

## THERMOCOUPLE* CALIBRATION

Thermocouple Number: 

# 3 Date:
Technician: C.

Media 20 70 150

: Std Used Reference Deg F (To) Reference Corr Temp (deg R) deg F + 460 Probe Temp (deg F) 

# ig.o 150,0 Probe Temp (deg R), deg F +460 Difference (degrees) % Diff Abs. T (Renkin)

Diff. less than 1.5% at all points. (Yes/No)

. . Graph Attached (Yes/ No) Extrapolated Range with Diff. <= 1.5% to

• Description of the thermocouple's. function:

If not acceptable, describe corrective procedures undertaken:

### THERMOCOUPLE CALIBRATION

500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 REFERENCE TEMPERATURE, deg.R 1700 1600 uSI 500 P1400 g1300 Lu 200 Lu H1'50 Lu —11:130 

### a_ o 900 0 800 2 700 Lu 600 500 400 400 —0—Calibration Curve - Unit Under Test — Upper Limit of Calibration
—Lower Limit of Calibration —Extrapolated Calibration Curve 

### THERMOCOUPLE ID C-5-I Regression R Squared = 0.999996 

# 1111 BARR THERMOCOUPLE CALIBRATION

THERMOCOUPLE ID C

- 

## 5

- 

## I Cal;Date: 12/27/2004 

## Meter In or Out CALIBRATION TECHNICIAN: NRS
REFERENCE STANDARDS TRACEABILITY DATE LABORATORY

Hart Scientific 9103-A sin Al B289 Report No: Al B0718 12/11/2003 Hart Scientific Hart Scientific 9140 s/n Al B086 Report No. Al B2024 12/11/2003 Hart Scientific 

### Temperature Calibraion Points 20 70 150 Reference Deg F (To) 20 70 150 Probe Temp (deg F) 20 69 148 

### Reference Temp (deg R) deg F + 460 480 530 610 Probe Temp (deg R), deg F + 460 480 529 608 Difference (degrees) 

# o 1 2 % Diff Abs. T 0.0% 0.2% 0.3% Is difference less than 1.5% at all measured points? YES

Are extrapolated limits less than 1.5%? YES FAHRENHEIT CALIBRATION RANGE -20 1200 If not acceptable, describe corrective action:

### Engineering Company 

## THERMOCOUPLE CALIBRATION

Thermocouple Number: 

### Ye- Date:

. 

### t
Technician:

Media 20 70 150

Std Used b-3 Reference Deg F (To) 2_0

- 

### TO t Reference Corr Temp (deg R) deg F + 460 4 

## 1?0 .5

- 3 0 Cp 0 Probe Temp (deg F) 

## Z 0 (+9 Probe Temp (deg R), deg F + 460 

### 52.9 (908 Difference (degrees) 

## o '
% Diff Abs. T (Renkin) 0.0 o.2, 0.3

Diff, less than 1.5% at all points Graph Attached Extrapolated Range with Diff. <= 1.5% C)/ No ), . CD' No)

to

Description of the thermocouple's4unction:

If not acceptable, describe corrective procedures undertaken:

### THERMOCOUPLE CALIBRATION

THERMOCOUPLE ID C-5-0

Regression R Squared = 1

1 14;7.44, 

### 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 REFERENCE TEMPERATURE, deg.R 1700 1600 fill 500 121400 300 1

- 1200 01 1 F 1 00 w

— 1 1400 a. 

# O •

900 0 O 800 2 700 600 500 400 400 --A— Calibration Curve - Unit Under Test Upper Limit of Calibration —Lower Limit of Calibration —Extrapolated Calibration Curve 

# THERMOCOUPLE CALIBRATION 

# BARR Ota 

## THERMOCOUPLE ID C-5-0 Cal; Date: 12/2712004 

## Meter In or Out CALIBRATION TECHNICIAN: NRS
REFERENCE STANDARDS TRACEABILITY DATE LABORATORY

Hart Scientific 9103-A sin Al B289 Report No A1B0718 1211112003 Hart Scientific Hart Scientific 9140 s/n A1B086 Report No. A1B2024 12/11/2003 Hart Scientific 

### Temperature Calibraion Points 20 70 150 Reference Deg F (To) 20 70 150 Probe Temp (deg F) 19 69 149 

### Reference Temp (deg R) deg F + 460 480 530 610 Probe Temp (deg R), deg F + 460 479 529 609 Difference (degrees) 1 1 1 % Diff Abs. T 02% 0.2% 0.2% Is difference less than 1.5% at all measured points? YES

Are extrapolated limits less than 1.5%? YES FAHRENHEIT CALIBRATION RANGE -20 1200 If not acceptable, describe corrective action:Media 20 70 150

. Std Used 

### b-8

• Reference Deg F (To) Z-0
Reference * Corr Temp (deg R) deg F + 460 

## qko

. 

### 3o
Probe Temp (deg F) (p 

### c\ 

# 1 Probe Temp (deg R), deg F + 460 Difference (degrees)
% Diff Abs. 

### T (Renkin) 

### CoOct 4 

## N-et

f 

### 0 Z. 2._ 

# Szn Engineering Company 

## THERMOCOUPLE CALIBRATION

(0/ Thermocouple Number: - 

## 7

- q_ Date:

. 

### t 

### `4
Technician:

Description of the thermocouple's.function: 

# C oA,L- 

# / 1. 1,,,.d 'Ate, S" t.)GM 0 v.+ e.4-

If not acceptable, describe corrective procedures undertaken: No) (69 No)

to Diff, less than 1.5% at all points Graph Attached Extrapolated Range with Diff. <= 1.5%

### 950 

# c 

# si

900 

# 9c6

800 

# 801

750

- 

## 652-

700



# _ 702-

650 

# CpS

- 3

600 

## Co 02_

550 

# 5:51

500 

# ST O0

450 

# lig

400 

# '100

350 

# 3co

300 

# 3o1

250 

# 2-51

200 

## 201
150 

# 1S3

100 

## 10

0 

## 0 Reference Pyrometer

1000 • 

# i

850

50

-50 A IP 

# PYROMETER CALIBRATION Engineering Company



## Pyrometer Number 

# b---1 Pyrometer Reference: C.,L3u0 -14.-1600F 

## Date: 

## Technician: 

# Nas

Notes:

# PYROMETER CALIBRATION

Pyrometer Number: Pyrometer Reference: 

## 0...—.30c
, —( 0-6-01---

Reference (°F) Reference (°C)

1000 538
950 - 510
900 482
850 454
800 • 427

• 750 399
700 371
650 343 

# soo,

. 316

•• 550 288
500 260
450 232
400 204
350 177
300 149
250 121

. 200 93
150 67
100 38

- 50 10
0 -18
-46 

### Date: Technician: ki



# I Pyrometer 

### (° ) 

## be, 

# 1 

# 1 _,So

- 700 

## 4,7 :50 

# S1Y 5

. 0

I./



# i?



# 117 Pig

—



### Notes:

# BARR Manometer Calibration Sheet

Manometer Number Alnor M-9H Leak Check: Date of Calibration 8/15/2005 Negative 0.0 @3" Technician JMM Positive 0.0 @3"

Oil Manometer


### 0.06 Di. ital Manometer


### 0.06 Pass/Fail


### Pass
0.20 Pass
0.5 0.50 Pass

0.8 

### 0.79 Pass
0.99 Pass

1.5 

### 1.44 Pass
2 1.93 Pass
1

. 

### - 2.5 

### 2.46 Pass
2.95 Pass
3.45 Pass

0.06 0.06 Pass

0.2 

### 0.20 Pass

0.5 

### 0.50 Pass

0 > 0.8 

### 0.78 Pass

ca 

### 0.98 Pass a) z • 

### 1.45 Pass
1.97 Pass

2.5 

### 2.48 Pass
2.96 Pass

3.5 

### 3.46 Pass

# BARR

ELECTRONIC MANOMETER CALIBRATION

Manometer I.D. Number: Leak Check: Date of Calibration : 

## Ics 

## — 5 — Negative: 

### 0 ,0 @ 3" Technician: U AAA Positive: 

# es.,Z) @ 3"

Positive:

Negative: Reference Oil Manometer Electric Manometer

0.06"
0.2" 0 Are 0 0.5" 0 t 

### CD 0.8"

1" 1.5" 

# I

, c i L i
2" / . 1.: 1 2.5"

3"
3.5" Reference Oil

Manometer Electric Manometer

0.06" 6 1 

# 06
0.2" 0.5". 

# 0 5

- 0

0:8"

1"
1.5" 

# 1 ret5'
2"
2.5" • .? i 1 

# e

3" (9 A 

# T6

Notes: 

### C4 I :6

- 4\0 

# On, laCev - IA 1 -4 

# Pt 1

- 1 "-e--1 -6 V A LL /

Barr Engineering Co. 4700 W. 77th St Minneapolis, MN 55437 (952) 832-2600

### j 

# 1I W-41.30-4.1 t‘ : 1.1V3t

ft-W•Fkv. 

# -17

. 0.•••• • 

# A Engineering Company S-Type Pitot Tube Geometry Check

Pitot Tube Number; Length: 

### tp I
Function: M-5 Probe / . Inspection Date: 

### )2-Z I. -0 Li

Technician: 

# AN2S

1. Are face openings perpendicular to tube axis? 1a. If NO, is angle less than 10 0 ? 

### JYES (goto2) 

# D NO (go to 1a) 

# El YES ( go to 2) 0 NO (discontinue use)

2. Are face openings parallel to longitudinal axis? 2a. If NO, is angle less than 5 0 7 0 YES ( go to 3) • 1:Z NO (go to 2a) 1E1 YES ( go to 3) • 0 NO (discontinue use)

3. Are legs of equal length? YES ( go to 4) 0 NO (go to 3a) 3a. If NO, is difference less than 1/8 inch? 0 YES ( go to 4) • 0 NO (discontinue use)

0 

# 1r

4. Are center-lines of legs coincident? 

### gl YES ( go to 5) 0 NO (go to 4a) 4a. If are center-lines of face openings less than 1/32 inch? 0 YES ( go to 5) 0 NO (discontinue use)

5. Does this pitot tube pass all of tile oli r ariteria? 

# E YES 0 NO / I 

### I
Technician Signature: •. 1 

## f 

# 11911 t-,2Control Module C-5 Barometric Pressure 29.12 Project: Routine Leak checks Previous Y - 0.9953 Date: 11/21/2005 Negative -

- ok >5 W.C. Previous Delta H - 1.9920 Technician: NRS Positive - ok > in.Hg

Orifice

Diff Presure H Dry Gas Volume Cubic Feet Wet Test Volume, Cubic Feet Dry Gas Meeter Temp, F Wet Test Meter Temp, F Elapsed Time of Cal. Point Meter Coefficient Y Orifice Coefficient

dHp Inlet I Outlet Nominal 0.500 Final 14.075 Final 5898.00 Final 71.0 Final 70.0 Final 71.5 Minutes 12.0 SEC 55

0.9979 1.9379 Actual

0.50 Initial 9.085 Initial 5893.00 Initial 70.0 Initial 69.0 Initial 71.5 Minutes

12.92 Total 4.990 Total 5.00 Average 70.5 Average 69.5 Average 71.5 1 70.0 I Nominal

1.000 Final 19.565 Final 5903.50 Final 73.0 Final 70.0 Final 71.5 Minutes 9.0 SEC 10.01

0.9980 1.9503 Actual

1.00 Initial 14.570 Initial 5898.50 Initial 72.0 Initial 70.0 Initial 71.5 Minutes

9.17 Total 4.995 Total 5.00 Average 72.5 Average 70.0 Average 71.5 I 71.3 Tm Nominal 2.000 • Final 25.065 Final

. 5909.00 Final 75.0 Final 71.0 Final 71.0 Minutes 6.0 SEC 34.8

0.9959 2.0060 Actual

2.00 Initial 20.060 Initial 5904.00 Initial 73.0 Initial 70.0 Initial ' 71.5 Minutes

6.58 Total 5.005 Total 5.00 Average 74.0 Average 70.5 Average 71.3 I 72.3 Tm I Nominal 3.000 Final 31.095 Final 5915.00 Final 77.0 Final 71.0 Final 71.0 Minutes 5.0 SEC 22.02

0.9932 1.9981 Actual

3.00 Initial 26.075 Initial 5910.00 Initial 75.0 Initial 71.0 Initial 71.0 Minutes

5.37 Total 5.020 Total 5.00 Average 76.0 Average 71.0 Average 71.0 I 73.5 Tm 11 Nominal 4.000 Final 37.135 Final 5921.00 Final 78.0 Final 71.0 Final 71.0 Minutes 4.0 SEC 39.74

0.9891 2.0104 Actual

4.00 Initial 32.100 Initial 5916.00 Initial 77.0 Initial 71.0 Initial 71.0 Minutes

4.66 Total 5.035 Total 5.00 Average 77.5 Average 71.0 Average
• 71.0 1 74.3 Tm 11 Average 0.9948 1.9805

M5APR.WQ1

### Routine Dry Gas Meter Calibration 

# BARR

Control Module Number: 

### C-5 - Leak Checks Barometric Press.: 

# 29. ?

- 

### Date: 

### 11

- 

### Z(

- 

### 0 Positive 

### ‘

- '7 , k at 5 in.H20 Previous Y: 

### 0.99513
Technician: A)/2_5 

### Negative ok 

### at 15 

### in.Hg Previous AH:

Orifice Diff Pres.

(°H 2 0) Dry gas Volume

(Ft) Wet Test Volume



### (Fe) Dry Gas Meter Temp ( -, 0F) • Wet Test Meter Temp (

- 0F) Elapsed Time of Calibration Point Meter Coefficient (Y) Orifice Coefficient

AH@ Inlet Outlet Nominal O , 5- Final 

### P.075 - Final 

## 5P)S 1 Final 

### 7 i Final 

### 70 Final

- 

## 11S Minutes 

## 11 Seconds <-

Actual Initial Initial _CY93 Initial 70 Initial • (c. 5 Initial 71 , STotal 

## (.4

. 619 Total 

## 5-, 0 Average 

### 70 S - Average Average 

### <D9,S Tm Average 

### it's. - -r.1 -1 Minutes 

### 12 , `7 7

- 

### -/ '( / i i• /cr

- ' -4

- f ■ f1:7 -

Orifice Diff Pres.

("H 2 0) Dry gas Volume

(Ft'') Wet Test Volume



### (Fe) Dry Gas Meter Temp (

- 0F) Wet Test Meter Temp (

- vF) Elapsed Time of Calibration Point Meter Coefficient (Y) Orifice Coefficient

AH@ Inlet Outlet Nominal

( - 0 Final /5 .69S -- Final S

- 50'. S" Final 

### 73 Final 

### 70 Final 

### 1 i.S

. Minutes 

### 't Seconds 

### to. 0 /-

Actual Lo Initial 

### P

- 1.51 Initial 

### SM=5

. Initial 

## /2. Initial 

### 10 Initial 

### 7 (.Sr Total 

## 4.995 - Total 

### 5

- .0 Average 

### -77 ,s -- Average 

### -7 0 Average 

### -7 i , s -- Mini I e 5 

### 9 . 

### 17

p- Average Tm

- M

Orifice Diff Pres.

(H 2 O) Dry gas Volume

(Ft) Wet Test Volume

(Fe) Dry Gas Meter Temp ( -,,, F) Wet Test Meter Temp (`‘ 5, F) Elapsed Time of Calibration Point Meter Coefficient (Y) Orifice Coefficient

AH@ Inlet Outlet Nominal 

### 2.0 Final 

### 'ZS

- ,06c Final 

### 5

- 905 Final

- 

## 15 - Final Final

- 

## I( Minutes Seconds



### .. - 4- Actual 2.0 Initial 

### Z0.0Co Initial 

### 590c/ Initial 

### 73 Initial 

### 70 Initial 

### 7 1 , s - ;i;'-



### - 

## e Total , DO .5 — Total

s -, 

### 0 Average 

### 7 q Average 

### io.7" Average Minutes 

### (S 2 

### -o

.. ---,,,,,_. Average Tm



### . .. .)



### _, _ Orifice Diff Pres.

("H 2 O) Dry gas Volume

(Ft'') Wet Test Volume



### (Ft) Dry Gas Meter Wet Test Meter Temp (

- 0F) Elapsed Time of Calibration Point Meter Coefficient (Y) Orifice Coefficient

AH@ 

### Inlet Outlet Nominal

- S . 0 Final 1( 

### 45 C Final


### s -- 9 

### 1 i Final

- 

### 71 Final

- 

### 1 ( Final 

### i ( Minutes • 

### S Seconds 2..7_ .02_=4NI•• Actual 

## 3 .0 Initial 

## 2(0.075 Initial 

### S

-- 700 Initial 

### IS Initial 

### 71 Initial

- 

### 1 ( .,-, •-•tVAI



### -- . ,,'-- Total .5.02_ Total 5. 0 Average 7L Average "1 ( Average --/ 

## 1 5% 37 Minutes 

### t . 9 ScY t Average Tm

• -.-A- ,

,.. , • -- Orifice Diff Pres.



### ("H 2 0) Dry gas Volume



### (Fe) Wet Test Volume

(Ft') Dry Gas Meter Temp ( -, E , F) Wet Test Meter Temp ( , PF) Elapsed Time of Calibration Point Meter Coefficient (Y) Orifice Coefficient

AH@ Inlet Outlet Nominal Li. 0 Final 

## 31, f35 - Final 

## 59 11 Final 

## 7V Final 

## 11 Final 

## 1 1 Minutes Seconds 

### 3 9 ,

--- 1(1 i77:1"

* Actual

I V ) Initial 32 , 

### lb Initial 

### 'f 2... Initial 

### '1

-- 1 Initial 

### -/ ( Initial 

### 7! Total 5: 

### 0 33 - Total 

### c. 0 Average

- 

### 11.5" Average Average

- 

### II Average 

### 1 Tm Minutes 

### '1. &G

- • z_

. .,91

. 94

... . Meter Average 

### 0.9'3I 1.98o5

# Appendix E
Cylinder Gas Certifications

# III

I 6531 BOX SPRINGS BLVD. • RIVER I SIDE, P CA92507 I 

# NC

. TELEPHONE (909) 653-6780 • FAX (909) 653-2430


# REPORT OF ANALYSIS EPA PROTOCOL GAS MIXTURES

BARRO1 TO: Sam Foss Barr Engineering Co 7390 OHMS Lane Edina MN 55439-2330 

### DATE: June 25 2004

CUSTOMER ORDER NUMBER: 20040420ASMF2



### CONCENTRATION(v/v) REFERENCE COMPONENT ± EPA UNCERTAINTY STANDARD ANALYZER MAKE, MODEL, SIN, DETECTION 

### EXPIRATION DATE REPLICATE ANALYSIS DATA CYLINDER NO: 

# CC376
VARIAN MODEL 1860 TCD 06/25/04 Carbon Dioxide 8.87 ± 0.09% GMIS S/N NONE 06/25/07 8.86% CYLINDER #: THERMAL CONDUCTIVITY 8.88%
CC51172 GAS CHROMATOGRAPHY 8.86%
@17.98% LAST CAL DATE: 06/25/04 MEAN: 8.87%

VARIAN MODEL 1860 TCD 06/24/04 Oxygen 8.85 ± 0.09% GMIS S/N NONE 06/24/07 8.89% CYLINDER #: THERMAL CONDUCTIVITY 8.87% Nitrogen Balance CC81204 GAS CHROMATOGRAPHY 8.79% CYLINDER PRESSURE: 2000 psig @9.88% LAST CAL DATE: 06/23/04 MEAN: 8.85%

ppm = gmole/mole % = mole-%
The above analyses were performed in accordance with Procedure G1 of the EPA Traceability Protocol, Report Number EPA-600/R97/121, dated., SeptOmber 1997. This cylinder sh/ d röt be11 If the pressure is less than 150 psig.



### tay r J T .MARRIN

The only liability of this company for gas which fails io comply with this analysis shall be replacement or reanalysis thereof by the company without extra cost,
STANDARD CALIBRATION GASES IN ALUMINUM CYLINDERS 

### ANALYST: M.S.CAL4OUN 

### APPROVED: er - Tri 1 /COMPONENT
CYLINDER NO: CONCENTRATION(0) REFERENCE EPA UNCERTAINTY STANDARD 

## CC74046 ANALYZER MAKE, MODEL, SIN, DETECTION EXPIRATION REPLICATE DATE ANALYSIS DATA

MONITOR LABS MODEL 8440 04/07/04 04/14/04
PPRI GMIS S/N 136 04/14/06 24.87 ppm 24.86 ppm CYLINDER #: coNTINuous 24.80 ppm 24.71 ppm
CC65129 CHEMILUMINESCENCE 24.82 ppm 24.76 ppm @19.86 ppm LASTCALDATE: 04/06/04 MEAN: 24.83 ppm 24.78 ppm Nitric Oxide 24.81 t 0.25 NOx 24.81 ppm Nitrogen, 02-Free Balance CYLINDER PRESSURE: 2000 psig 

# Iii SCOTT

-

6531 BOX SPRINGS BLVD. 0 RIVER I SIDE, P CA I 92507 TELEPHONE (909) 653-6780 0 FAX (909) 653-2430



# REPORT OF ANALYSIS EPA PROTOCOL GAS MIXTURES

BARRO1 TO: Sam Foss Barr Engineering Co 7390 OHMS Lane Edina MN 55439-2330 DATE: April 16 2004

CUSTOMER ORDER NUMBER: 20040323ASMF2

ppm = I/mole/mole % = mole-%
The above analyses were performed in accordance with Procedure G1 of the EPA Trac bility Protocol, Report Number EPA-600/R97/121, dated September 1997. This cylinder should not be used if the pressure is less than 150 psig.

ANALYST; APPROVED: 

### B.M.MARRIN J.T.MARRIN
The only liability bf this company for gas which falls to comply with this analysis shall be replacement or reanalysis thereof by the company without extra cost.
STANDARD CALIBRATION GASES IN ALUMINUM CYLINDERSppm m gmole/mole % m mole—% 

### The above analyses were performed in accordance with Procedure G1 of the EPA Trac EPA-600/R97/121, dated September 1997. This cylinder should not be used If the pressure is less than 150 psig, ility Protocol, Report Number

IN J.T.MARRIN 

### APPROVED: ANALYS 

# III 

# 1

6531 BOX SPRINGS BLVD. • RIVER I SIDE! C A92507 I 

# NC

. TELEPHONE (909) 653-6780 • FAX (909) 653-2430



# REPORT OF ANALYSIS EPA PROTOCOL GAS MIXTURES

BARRO1 TO: 

### Sam Foss Barr Engineering Co 7390 OHMS Lane Edina MN 55439-2330 DATE: April 16 2004



### CUSTOMER ORDER NUMBER: 

### 20040323ASMF2

COMPONENT CYLINDER NO: CONCENTRATION(v/v) REFERENCE EPA UNCERTAINTY STANDARD 

## CC74110 ANALYZER MAKE, MODEL, SIN, DETECTION EXPIRATION REPLICATE DATE ANALYSIS DATA

50.3 t 0.3 50.3 

### ppm Balance 2000 

### psig PPm GMIS CYLINDER #: CC108765 @51.4 ppm Nitric Oxide NOx Nitrogen ,02-Free CYLINDER PRESSURE: MONITOR LABS MODEL 8440
S/N 136
CONTINUOUS
CHEMILUMINESCENCE LAST CAL DATE: 04/06/04 04/07/04 04/14/04 04/14/06 50.4 ppm 50.3 ppm 50.2 ppm 50.4 ppm 50.2 ppm 50.3 ppm MEAN: 50.3 ppm 50.3 ppm

The only liability of this company for gas which fails to comply with this analysis shall be replacement r reanalysis thereof by the company without extra cost.
STANDARD CALIBRATION GASES IN ALUMINUM CYLINDERS

### COMPONENT ANALYZER MANE, MODEL, 8/N, DETECTION 

### EXPIRATION REPLICATE DATE ANALYSIS DATA CONCENTRATION(v/v) REFERENCE ± EPA UNCERTAINTY STANDARD.

% = mole-% ppm = omole/mole



### ANALYST: APPROVED: D.C.MARRIN .T.MARRIN 

### CYLINDER NO: 

## CC12639 MONITOR LABS MODEL 8440 07/06/05 07/21/05
Nitric Oxide 90.5 ± 0.8 ppm GMIS E/N 136 07/21/07 90.3 ppm 90.6 ppm NOx 90.5 ppm CYLINDER #: CONTINUOUS 90.5 ppm 90.7 ppm Nitrogen,02-Free Balance CC68777 CHEMILUM/NESCENCE 90.6 ppm 90.3 ppm CYLINDER PRESSURE: 2000 psig @102.4 ppm

. LAST CAL DATE: 07/18/05 MEAN: 90.5 ppm 90.5 ppm



### The above analyses were performed in accordance with Procedure G1 of the EPA Trace 'lity Protocol, Report Number EPA-600/R97/121, dated September 1997. This cylinder should not be used if the pressure is less than 150 psig.

. . •

The only liability of this company for gas which falls to comply with this analysis shall be replacement or reanalysis thereof by the company without extra cost. 

# Ii SCOTT-MArRIN, INC. 6531 BOX SPRINGS BLVD. • RIVERSIDE, CA 92507 TELEPHONE{951) 653-6780 • FAX (951) 653-2430



# REPORT OF ANALYSIS EPA PROTOCOL GAS MIXTURES

BARRO1 TO: 

### Jason McCann Barr Engineering Co 4700 W 77th St 

### Minneapolis, MN 55435-4803 DATE: July 

### 25 2005

CUSTOMER ORDER NUMBER: 20050719AJMM

-• • • • . — A.

- "sraiuova 0.41 /VA wi+.41 ow. OCW.7.

- w"

–

won'AZ,"Zw=w;7ww -n 7++

‘,.ow o`ww

— ww ow+ ow+ ow+ AM Am AM AM eV. AM NV% MA Ohl eVei 0. , " rWt n....• ■ ••0 A+, evA A+, .+A AAA AAA A+, AM .MA Mr, Oegi OM writ •••• ■ • eon Am Am /VA ergo, ■ • ■ ••• ovIA or, "...1 MA MA A/A MI Mon MA M.* AM AM ■ •• ■ 40.1.1 esh1 MN eV. AV* IA. een en% ee ■■ OM

Ann, nal inn A -roans) ra A oce lea All 11111a11111A noncom

### DATE: September 16 2005 

### BARRO1 TO: Jason McCann Barr Engineering Co 4700 West 77th Street Minneapolis MN 55435-4803

CUSTOMER ORDER NUMBER: 

### 20050719AJMM

REFERENCE STANDARD COMPONENT
CYLINDER NO: CONCENTRATION(v/v) t EPA UNCERTAINTY 

## CA031 45 ANALYZER EXPIRATION REPLICATE MAKE, MODEL 6/M, DETECTION 

### DATE ANALYSIS DATA

Nitric Oxide NOx Nitrogen ,02-Free 

### 251.6 t 1.6 ppm 251.6 ppm

Balance 

# lull

6531 

### BOX SPRINGS BLVD: • RIVERSIDE, 92507 I 

# NC

. TELEPHONE (951)653-6780 • FAX (951) 653-2430



# REPORT OF ANALYSIS EPA PROTOCOL GAS MIXTURES

ev, n••••• ■ V ■ 0.1.1 AM Am AM Am AAA Am Am Am ...IAA" AM Am Am Am AA AnA nm eon ov, em Ann ov, IAA AM Am AS1 Oen eV. AM MA AM Awl /vv. AN AM Oh, ..6.5 IAA •• ■ •• ■ oWl /VA AM Am Aer
, Ao. A

. , AM AM M..... en* WW1 lee ■ AV, M6 AM AM AM AM /MN er, MI% NA !An A.. OM AN AAA AIA Am Am Ann ...In eh, /VA Am AA eh% NA .1.1 MA .1.16 NA OM !eV, ••• ■ • eeet emel AM AM erm AM Am Am AM AM Ann A., AM AM Am



### CYUNDERPRESSURE:2000 psig MONITOR LABS MODEL 8440 

### sill 136 CONTINUOUS CESMILUMINESCENCE LAST CAL DATE: 08/22/05 08/29/05 09/08/05 09/08/07 251.9 ppm 251.7 ppm 251.5 ppm 251.8 ppm 251.1 ppm 251.7 ppm 

### PAEAN: 251.5 ppm 251.7 ppm GHIS CYLINDER #: CC1839 @249.8 ppm

% . mole-% ppm . omole/mole



### ANALYST: APPROVED: The above analyses were performed in accordance with Procedure G1 of the EPA Traceability Protocol, Report Number EPA-600/R97/121, dated September 1997, This cylinder should not be used if the pressure is less than 150 psig.

The only liability of this company for gas which falls to comply with this analysis shall be replacement or reanalysis thereof by the company without extra cost,
STANDARD CALIBRATION GASES IN ALUMINUM CYLINDERS

# Appendix F
Process Operating Data

### Northshore Mining Line 11 Process Data December 21, 2005

12/21/2005 3:30 0.0 120.8 12/21/2005 3:35 149.7 143.7 12/21/2005 3:40 211.6 166.3 12/21/20053:45 210.6 172.1 12/21/2005 3:50 204.3 177.7 12/21/2005 3:55 209.4 140.7 12/21/2005 4:00 210.9 103.3 12/21/20054:05 211.4 131.9 12/21/2005 4:10 213.2 161.2 12/21/2005 4:15 209.9 146.5 12/21/2005 4:20 206.6 131.4 12/21/2005 4:25 206.5 128.3 12/21/2005 4:30 207.2 125.3 12/21/2005 4:35 207.5 122.3 12/21/2005 4:40 205.9 119.4 12/21/2005 4:45 207.6 127.2 12/21/2005 4:50 208.7 135.2 12/21/2005 4:55 209.3 135.4 12/21/2005 5:00 210.5 135.5 12/21/2005 5:05 212.7 138.6 12/21/2005 5:10 209.3 141.8 12/21/2005 5:15 209.2 141.1 12/21/2005 5:20 209.3 140.4 12/21/2005 5:25 209.4 139.6 12/21/2005 5:30 209.5 138.9 12/21/2005 5:35 209.8 138.1 12/21/2005 5:40 209.0 137.4 12/21/2005 5:45 208.1 136.6 12/21/2005 5:50 208.9 135.9 12/21/2005 5:55 210.9 132.5 12/21/2005 6:00 211.9 129.1 12/21/2005 6:05 211.6 130.5

. 

### 12/21/20056:10 211.3 132.0 12/21/2005 6:15 209.5 131.7 12/21/2005 6:20 209.0 131.4 12/21/2005 6:25 209.8 131.1 12/21/2005 6:30 221.4 130.8 12/21/2005 6:35 254.7 129.0 12/21/2005 6:40 266.7 127.1 12/21/2005 6:45 250.0 130.3 12/21/2005 6:50 258.2 133.5 12/21/2005 6:55 258.9 133.0 12/21/2005 7:00 255.4 132.6 12/21/2005 7:05 257.8 132.1 12/21/2005 7:10 261.6 131.6 12/21/2005 7:15 260.0 131.1 12/21/2005 7:20 262.6 130.6 12/21/2005 7:25 262.5 132.0 12/21/2005 7:30 262.8 133.4 12/21/2005 7:35 261.7 132.9 12/21/2005 7:40 258.1 132.4 12/21/2005 7:45 254.5 131.9

### Line 11 Process Data December 21, 2005

12/21/2005 7:50 250.0 131.4 12/21/2005 7:55 251.1 130.8 12/21/2005 8:00 251.1 130.3 12/21/2005 8:05 251.1 129.3 12/21/2005 8:10 249.7 128.3 12/21/2005 8:15 247.9 127.3 12/21/2005 8:20 249.1 126.2 12/21/2005 8:25 249.9 125.2 12/21/2005 8:30 247.5 124.2 12/21/2005 8:35 247.2 125.1 12/21/2005 8:40 246.2 126.0 12/21/2005 8:45 245.7 126.9 12/21/2005 8:50 246.8 127.7 12/21/2005 8:55 246.4 128.6 12/21/2005 9:00 246.0 129.5 12/21/2005 9:05 244.3 129.4 12/21/2005 9:10 243.7 129.3 12/21/2005 9:15 244.5 129.2 12/21/2005 9:20 245.3 129.1 12/21/2005 9:25 245.6 129.0 12/21/2005 9:30 247.3 128.9 12/21/2005 9:35 247.5 127.6 12/21/2005 9:40 244.5 126.2 12/21/2005 9:45 244.5 127.1 12/21/2005 9:50 244.4 128.1 12/21/2005 9:55 246.8 127.9 12/21/2005 10:00 254.2 127.7 12/21/2005 10:05 262.0 127.4 12/21/2005 10:10 254.2 127.2 12/21/2005 10:15 254.6 127.6 12/21/2005 10:20 251.8 127.9 12/21/2005 10:25 253.8 128.3 12/21/2005 10:30 253.1 128.6 12/21/2005 10:35 250.7 129.0 12/21/2005 10:40 251.0 129.4 12/21/2005 10:45 253.2 129.7 12/21/2005 10:50 252.7 130.1 12/21/2005 10:55 245.3 130.4 12/21/2005 11:00 257.8 130.8 12/21/2005 11:05 255.7 128.7 12/21/2005 11:10 254.4 126.5 12/21/2005 11:15 256.1 127.1 12/21/2005 11:20 256.3 127.7 12/21/2005 11:25 256.2 128.2 12/21/2005 11:30 256.5 128.8 12/21/2005 11:35 257.2 129.4 12/21/2005 11:40 257.1 129.9 12/21/2005 11:45 255.9 130.5 12/21/2005 11:50 253.6 131.1 12/21/2005 11:55 254.6 131.7 12/21/2005 12:00 255.8 132.2 12/21/2005 12:05 249.2 132.8 Northshore Mining

### Northshore Mining Line 11 Process Data December 21, 2005

12/21/2005 12:10 255.4 133.4 12/21/2005 12:15 249.8 132.8 12/21/2005 12:20 251.9 132.3 12/21/2005 12:25 257.1 131.7 12/21/2005 12:30 254.3 131.1 12/21/2005 12:35 254.4 130.6 12/21/2005 12:40 249.9 130.0 12/21/2005 12:45 253.8 131.7 12/21/2005 12:50 257.1 133.5 12/21/2005 12:55 250.7 135.2 12/21/2005 13:00 252.7 137.0 12/21/2005 13:05 255.3 135.7 12/21/2005 13:10 250.0 134.5 12/21/2005 13:15 251.2 135.9 12/21/2005 13:20 247.7 137.3 12/21/2005 13:25 243.7 135.0 12/21/2005 13:30 242.2 132.7 12/21/2005 13:35 240.7 132.5 12/21/2005 13:40 243.6 132.2 12/21/2005 13:45 242.1 72.5 12/21/2005 13:50 125.3 12.2 12/21/2005 13:55 18.7 63.4 12/21/2005 14:00 174.0 115.7 12/21/2005 14:05 233.1 121.7 12/21/2005 14:10 242.7 127.2 12/21/2005 14:15 236.9 128.9 12/21/2005 14:20 235.3 130.7 12/21/2005 14:25 239.4 132.4 12/21/2005 14:30 240.5 134.1 12/21/2005 14:35 240.8 135.8 12/21/2005 14:40 239.0 137.5 12/21/2005 14:45 247.8 136.5 12/21/2005 14:50 245.2 135.5 12/21/2005 14:55 251.0 134.4 12/21/2005 15:00 250.6 133.4 12/21/2005 15:05 244.4 132.3 12/21/2005 15:10 251.6 131.3 12/21/2005 15:15 251.5 130.2 12/21/2005 15:20 252.2 129.2 12/21/2005 15:25 250.6 130.2 12/21/2005 15:30 254.7 131.3 12/21/2005 15:35 256.2 132.4 12/21/2005 15:40 256.2 133.5 12/21/2005 15:45 254.1 134.6 12/21/2005 15:50 253.9 135.7 12/21/2005 15:55 254.1 135.4 12/21/2005 16:00 253.8 135.1 12/21/2005 16:05 252.2 134.9 12/21/2005 16:10 252.9 134.6 12/21/2005 16:15 255.1 134.3 12/21/2005 16:20 257.2 134.0 12/21/2005 16:25 258.0 133.8

### Line 11 Process Data December 21, 2005

12/21/2005 16:30 254.9 133.5 12/21/2005 16:35 256.5 133.7 12/21/2005 16:40 258.0 133.8 12/21/2005 16:45 255.8 134.0 12/21/2005 16:50 255.0 134.2 12/21/2005 16:55 257.0 134.4 12/21/2005 17:00 256.1 134.5 12/21/2005 17:05 255.1 134.7 12/21/2005 17:10 256.0 134.9 12/21/2005 17:15 257.9 135.1 12/21/2005 17:20 257.3 135.2 12/21/2005 17:25 256.6 135.4 12/21/2005 17:30 254.1 135.6 12/21/2005 17:35 254.4 135.8 12/21/2005 17:40 255.8 135.9 12/21/2005 17:45 255.7 134.7 12/21/2005 17:50 248.0 133.4 12/21/2005 17:55 258.1 73.1 12/21/2005 18:00 198.3 12.2 12/21/2005 18:05 29.5 11.6 12/21/2005 18:10 5.7 11.6 12/21/2005 18:15 2.5 11.7 12/21/2005 18:20 1.9 11.7 12/21/2005 18:25 1.3 11.7 12/21/2005 18:30 0.7 11.7 12/21/2005 18:35 0.1 86.3 12/21/2005 18:40 107.5 161.7 12/21/2005 18:45 155.9 154.8 12/21/2005 18:50 154.9 147.0 12/21/2005 18:55 151.9 150.3 12/21/2005 19:00 155.7 153.6 12/21/2005 19:05 199.9 146.0 12/21/2005 19:10 214.1 138.3 12/21/2005 19:15 209.6 130.6 12/21/2005 19:20 216.1 122.9 12/21/2005 19:25 214.2 130.8 12/21/2005 19:30 212.3 138.8 12/21/2005 19:35 212.7 140.7 12/21/2005 19:40 210.0 142.5 12/21/2005 19:45 235.8 139.2 12/21/2005 19:50 246.2 135.9 12/21/2005 19:55 241.0 134.6 12/21/2005 20:00 230.4 133.4 12/21/2005 20:05 245.1 137.2 12/21/2005 20:10 237.8 141.0 12/21/2005 20:15 229.4 140.8 12/21/2005 20:20 241.8 140.6 12/21/2005 20:25 241.4 138.1 12/21/2005 20:30 236.5 135.6 12/21/2005 20:35 236.9 136.2 12/21/2005 20:40 2363 136.9 12/21/2005 20:45 236.4 137.5 Northshore Mining

### Northshore Mining Line 11 Process Data December 21, 2005

12/21/2005 20:50 247.7 138.1 12/21/2005 20:55 255.9 135.1 12/21/2005 21:00 252.2 1321 12/21/2005 21:05 255.3 134.3 12/21/2005 21:10 256.8 136.6 12/21/2005 21:15 255.6 135.7 12/21/2005 21:20 253.8 134.7 12/21/2005 21:25 252.7 135.9 12/21/2005 21:30 244.6 137.1 12/21/2005 21:35 241.5 138.4 12/21/2005 21:40 241.3 139.6 12/21/2005 21:45 241.1 139.3 12/21/2005 21:50 240.5 138.9 12/21/2005 21:55 242.3 138.6 12/21/2005 22:00 242.0 138.2 12/21/2005 22:05 246.7 137.9 12/21/2005 22:10 247.0 137.5 12/21/2005 22:15 250.0 137.2 12/21/2005 22:20 253.0 136.8 12/21/2005 22:25 252.6 136.5 12/21/2005 22:30 252.2 136.1 12/21/2005 22:35 252.2 135.8 12/21/2005 22:40 252.9 135.5 12/21/2005 22:45 253.8 135.1 12/21/2005 22:50 254.1 134.8 12/21/2005 22:55 252.8 134.9 12/21/2005 23:00 257.0 135.0 12/21/2005 23:05 250.6 135.1 12/21/2005 23:10 258.6 135.2 12/21/2005 23:15 255.9 135.4 12/21/2005 23:20 256.7 135.5 12/21/2005 23:25 254.2 135.6 12/21/2005 23:30 254.5 135.7 12/21/2005 23:35 256.4 134.9 12/21/2005 23:40 256.6 134.1 12/21/2005 23:45 256.8 133.2 12/21/2005 23:50 255.5 132.4 12/21/2005 23:55 254.5 133.6 12/22/2005 252.4 134.8

### Line No. 6 Testing Date: 12/22/05 Fce Tonnage Gas Use Run No. Start Time End Time LTPH MCF/hr 1 08:00 - 09:00 102 67 2 09:17 - 10:17 107 68 3 10:35 - 11:35 101 68 Average 

### 103 68

Line 6 Timestamp 12/22/2005 VVVU301.PV VFU155.PV VVVU301.PV - VFU155.PV - SnapShot 102.4 65.0 12/22/2005 0:05 100.2 65.5 12/22/2005 0:10 98.0 66.1 12/22/2005 0:15 90.9 65.0 12/22/2005 0:20 83.8 63.9 12/22/2005 0:25 95.0 64.2 12/22/2005 0:30 106.3 64.5 12/22/2005 0:35 104.1 64.9 12/22/2005 0:40 101.8 65.2 12/22/2005 0:45 95.4 64.8 12/22/2005 0:50 89.0 64.3 12/22/2005 0:55 97.8 65.3 12/22/2005 1:00 106,8 66.3 12/22/2005 1:05 101.5 67.3 12/22/2005 1:10 96.1 68.3 12/22/2005 1:15 100.9 66.8 12/22/2005 1:20 105.8 65.3 12/22/2005 1:25 103.9 66.5 12/22/2005 1:30 101.9 67.6 12/22/2005 1:35 99.9 66.9 12/22/2005 1:40 97.9 66.1 12/22/2005 1:45 106.2 65.3 12/22/2005 1:50 114.5 64.5 12/22/2005 1:55 103.6 65.0 12/22/2005 2:00 92.4 65.5 12/22/2005 2:05 104.5 66.0 12/22/20052:10 116.8 66.5 12/22/2005 2:15 109.7 67.0 12/22/2005 2:20 102.5 67.4 12/22/2005 2:25 110.2 67.9 12/22/2005 2:30 118.0 68.4 12/22/2005 2:35 114.9 66.7 12/22/2005 2:40 111.6 64.9 12/22/2005 2:45 101.9 65.1 12/22/2005 2:50 92.1 65.4 12/22/2005 2:55 93.8 65.6 12/22/2005 3:00 95.6 65.9 12/22/2005 3:05 97.4 64.4 12/22/2005 3:10 99.2 62.8 12/22/2005 3:15 104.4 63.0 12/22/2005 3:20 109.5 63.3 12/22/2005 3:25 109,9 63.5 Northshore Mining Line 6 Process Data December 22, 2005

### Northshore Mining Line 6 Process Data December 22, 2005

12/22/2005 3:30 110.2 63.8 12/22/2005 3:35 100.6 64.0 12/22/2005 3:40 90.9 64.2 12/22/2005 3:45 98.8 64.5 12/22/2005 3:50 106.9 64.7 12/22/2005 3:55 106.9 64.9 12/22/2005 4:00 106.9 65.2 12/22/2005 4:05 118.8 62.2 12/22/2005 4:10 130.9 59.2 12/22/2005 4:15 115.3 61.2 12/22/2005 4:20 99.4 63.4 12/22/2005 4:25 99.9 63.3 12/22/2005 4:30 100.6 63.1 12/22/2005 4:35 105.7 63.0 12/22/2005 4:40 110.8 62.9 12/22/2005 4:45 96.9 63.5 12/22/2005 4:50 82.9 64.2 12/22/2005 4:55 88.6 64.8 12/22/2005 5:00 94.5 65.5 12/22/2005 5:05 100.4 64.7 12/22/2005 5:10 106,4 63.9 12/22/2005 5:15 99.0 64.8 12/22/2005 5:20 91.4 65.7 12/22/2005 5:25 98.8 66.6 12/22/2005 5:30 106.3 67.5 12/22/2005 5:35 109.5 67.0 12/22/2005 5:40 112.6 66.5 12/22/2005 5:45 107.9 66.0 12/22/2005 5:50 103.0 65.5 12/22/2005 5:55 106.9 64.2 12/22/2005 6:00 110.9 62.9 12/22/2005 6:05 102.2 63.5 12/22/2005 6:10 93.4 64.1 12/22/2005 6:15 93.0 64.7 12/22/2005 6:20 92.7 65.3 12/22/2005 6:25 100.0 65.5 12/22/2005 6:30 107.3 65.6 12/22/2005 6:35 105.6 65.7 12/22/2005 6:40 103.7 65.8 12/22/2005 6:45 107.0 65.9 12/22/2005 6:50 110.4 66.0 12/22/2005 6:55 113.8 67.0 12/22/2005 7:00 117.2 67.9 12/22/2005 7:05 111.5 68.9 12/22/2005 7:10 105.7 69.8 12/22/2005 7:15 104.2 68.5 12/22/2005 7:20 102.8 67.1 12/22/2005 7:25 101,3 67.4 12/22/2005 7:30 99.8 67.8 12/22/2005 7:35 98.4 68.1 12/22/2005 7:40 96.9 68.5 12/22/2005 7:45 99.7 68.8

### Line 6 Process Data December 22, 2005 Northshore Mining

12/22/2005 7:50 102.5 69.2 12/22/2005 7:55 109.9 68.0 12/22/2005 8:00 117.4 66.7 12/22/2005 8:05 109.6 66.5 12/22/2005 8:10 101.5 66.3 12/22/2005 8:15 102.1 66.1 12/22/2005 8:20 102.7 65.9 12/22/2005 8:25 106.0 67.1 12/22/2005 8:30 109.5 68.3 12/22/2005 8:35 102.2 66.9 12/22/2005 8:40 94.9 65.5 12/22/2005 8:45 95.5 66.2 12/22/2005 8:50 96.2 67.0 12/22/2005 8:55 94.2 671 12/22/2005 9:00 92.2 68.4 12/22/2005 9:05 92.4 67.6 12/22/2005 9:10 92.5 66.8 12/22/2005 9:15 103.2 67.0 12/22/2005 9:20 114.0 67.3 12/22/2005 9:25 116.5 67.6 12/22/2005 9:30 118.9 67.9 12/22/2005 9:35 111.0 68.1 12/22/2005 9:40 103.0 68.4 12/22/2005 9:45 103.8 68.7 12/22/2005 9:50 104.8 69.0 12/22/2005 9:55 105.7 68.0 12/22/2005 10:00 106.7 67.0 12/22/2005 10:05 108.5 67.3 12/22/2005 10:10 110.3 67.7 12/22/2005 10:15 102.3 66.9 12/22/2005 10:20 94.3 66.1 12/22/2005 10:25 98.2 67.2 12/22/2005 10:30 102.2 68.3 12/22/2005 10:35 106.3 68.5 12/22/2005 10:40 110.4 68.6 12/22/2005 10:45 104.3 68.8 12/22/2005 10:50 98.1 69.0 12/22/2005 10:55 99.0 69.2 12/22/2005 11:00 100.0 69.4 12/22/2005 11:05 103.4 68.9 12/22/2005 11:10 106.9 68.4 12/22/2005 11:15 99.8 67.9 12/22/2005 11:20 92.6 67.4 12/22/2005 11:25 93.9 66.9 12/22/2005 11:30 95.3 66.5 12/22/2005 11:35 104.7 66.0 12/22/2005 11:40 114.3 65,5 12/22/2005 11:45 106.6 66.0 12/22/2005 11:50 98.8 66.5 12/22/2005 11:55 101.3 67.1 12/22/2005 12:00 103.8 67.6 12/22/2005 12:05 110.2 67.9

### Northshore Mining Line 6 Process Data December 22, 2005

12/22/2005 12:10 116.5 68.2 12/22/2005 12:15 116.6 68.5 12/22/2005 12:20 116.6 68.9 12/22/2005 12:25 114.2 68.4 12/22/2005 12:30 111.8 68.0 12/22/2005 12:35 106.1 67.5 12/22/2005 12:40 100.4 67.0 12/22/2005 12:45 94.7 66.6 12/22/2005 12:50 89.0 66.1 12/22/2005 12:55 95.1 65.7 12/22/2005 13:00 101.3 65.2 12/22/2005 13:05 97.4 66.3 12/22/2005 13:10 93.4 67.5 12/22/2005 13:15 98.6 67.5 12/22/2005 13:20 103.9 67.5 12/22/2005 13:25 99.0 67.6 12/22/2005 13:30 94.1 67.6 12/22/2005 13:35 102.7 67.6 12/22/2005 13:40 111.4 67.7 12/22/2005 13:45 110.4 67.7 12/22/2005 13:50 109.4 67.7 12/22/2005 13:55 102.2 67.7 12/22/2005 14:00 95.1 67.8 12/22/2005 14:05 95.5 67.3 12/22/2005 14:10 96.0 66.8 12/22/2005 14:15 96.5 66.4 12/22/2005 14:20 97.0 65.9 12/22/2005 14:25 97.5 65.5 12/22/2005 14:30 98.0 65.0 12/22/2005 14:35 95.9 66.2 12/22/2005 14:40 93.8 67.5 12/22/2005 14:45 91.7 67.5 12/22/2005 14:50 89.5 67.4 12/22/2005 14:55 95.5 67.4 12/22/2005 15:00 101.6 67.4 12/22/2005 15:05 96.7 68.7 12/22/2005 15:10 91.7 70.0 12/22/2005 15:15 100.3 68.7 12/22/2005 15:20 109.1 67.4 12/22/2005 15:25 128.9 66.1 12/22/2005 15:30 148.8 64.8 12/22/2005 15:35 124.0 64.9 12/22/2005 15:40 98.9 65.1 12/22/2005 15:45 98.2 65.2 12/22/2005 15:50 97.8 65.3 12/22/2005 15:55 97.4 66.6 12/22/2005 16:00 97.0 67.9 12/22/2005 16:05 100.2 66.5 12/22/2005 16:10 103.4 65.1 12/22/2005 16:15 103.1 65.0 12/22/2005 16:20 102.7 64.8 12/22/2005 16:25 108.1 65.9

### Line 6 Process Data December 22, 2005 Northshore Mining

12/22/2005 16:30 113.6 66.9 12/22/2005 16:35 109.9 65.3 12/22/2005 16:40 106.1 63.8 12/22/2005 16:45 99.7 63.2 12/22/2005 16:50 93.4 62.7 12/22/2005 16:55 100.9 62.2 12/22/2005 17:00 108.5 61.7 12/22/2005 17:05 106.6 61.2 12/22/2005 17:10 104.5 60.6 12/22/2005 17:15 97.8 61.1 12/22/2005 17:20 91.1 61.5 12/22/2005 17:25 96.7 62.0 12/22/2005 17:30 102.5 62.4 12/22/2005 17:35 99.8 62.3 12/22/2005 17:40 97.1 62.2 12/22/2005 17:45 107.1 62.1 12/22/2005 17:50 117.3 62.1 12/22/2005 17:55 105.0 62.8 12/22/2005 18:00 92.5 63.5 12/22/2005 18:05 88.7 64.2 12/22/2005 18:10 85.0 64.9 12/22/2005 18:15 89.8 64.2 12/22/2005 18:20 94.7 63.4 12/22/2005 18:25 95.5 62.7 12/22/2005 18:30 96.3 62.0 12/22/2005 18:35 88.1 61.2 12/22/2005 18:40 79.9 60.5 12/22/2005 18:45 82.6 61.0 12/22/2005 18:50 85.4 61.5 12/22/2005 18:55 78.1 62.0 12/22/2005 19:00 70.7 62.5 12/22/2005 19:05 89.9 63.0 12/22/2005 19:10 109.4 63.5 12/22/2005 19:15 103.6 64.0 12/22/2005 19:20 97.5 64.5 12/22/2005 19:25 101.8 65.0 12/22/2005 19:30 106.3 65.5 12/22/2005 19:35 103.4 64.3 12/22/2005 19:40 100.4 63.1 12/22/2005 19:45 103.8 62.9 12/22/2005 19:50 107.3 62.7 12/22/2005 19:55 98.8 62.5 12/22/2005 20:00 90.2 62.3 12/22/2005 20:05 97.3 63.9 12/22/2005 20:10 104.5 65.6 12/22/2005 20:15 99.1 65,7 12/22/2005 20:20 93.5 65.9 12/22/2005 20:25 92.6 66.0 12/22/2005 20:30 91.8 66.2 12/22/2005 20:35 98.3 66.4 12/22/2005 20:40 104.8 66.5 12/22/2005 20:45 108.8 65.5

### Northshore Mining Line 6 Process Data December 22, 2005

12/22/2005 20:50 112.8 64.4 12/22/2005 20:55 105.1 65,7 12/22/2005 21:00 97.3 67.0 12/22/2005 21:05 96.9 65.5 12/22/2005 21:10 96.6 63.8 12/22/2005 21:15 101.2 64.0 12/22/2005 21:20 105.7 64.2 12/22/2005 21:25 94.8 64.3 12/22/2005 21:30 83.7 64.5 12/22/2005 21:35 95.7 64.7 12/22/2005 21:40 107.9 64.9 12/22/2005 21:45 103.8 65.0 12/22/2005 21:50 99.6 65.2 12/22/2005 21:55 100.1 64,3 12/22/2005 22:00 100.7 63.4 12/22/2005 22:05 101,3 63.8 12/22/2005 22:10 101.9 64.2 12/22/2005 22:15 108.6 64.6 12/22/2005 22:20 115.2 65.0 12/22/2005 22:25 117.2 64.6 12/22/200522:30 119,0 64.2 12/22/2005 22:35 100.6 63.9 12/22/2005 22:40 82.0 63.5 12/22/2005 22:45 41.3 32.1 12/22/2005 22:50 0.4 0.3 12/22/2005 22:55 49.0 28.3 12/22/2005 23:00 98.4 56.9 12/22/2005 23:05 101.4 58.3 12/22/2005 23:10 103.9 59.4 12/22/2005 23:15 98.8 63.1 12/22/2005 23:20 93.6 66.9 12/22/2005 23:25 88.4 67.4 12/22/2005 23:30 83.3 68.0 12/22/2005 23:35 94.8 66,1 12/22/2005 23:40 106.4 64.2 12/22/2005 23:45 100.1 64.3 12/22/2005 23:50 93.6 64.4 12/22/2005 23:55 110.2 64.5 12/23/2005 127.0 64.6

# Appendix G

Stack Test Plan

### PART II. TESTING REQUIREMENTS



### The table below gives a summary of the pollutants to be tested and test methods.

Source Description * Limitation Basis of Pollutant Tested Pollutant Tested and Applicable Emission Limit Specific Methods/Procedures Required Citation

Pellet Indurating 

### No Limit — NA 40 CFR Part 60, Appendix A Furnaces

— 

### Test one 

### Sources being tested Waste Gas stack 

### to develop emission EPA Methods 1-4 from either Furnace 11 or Furnace 12, test one stack from 

### factors for use in emission inventories. Method 7E: 3 1-hr runs Testing on Fee 11 or Fce 12 and Furnace 6


### Fce 11 (SV104-105) Fce 12 (SV114-115) Fee 6 will include one airflow rate determined on the other associated waste gas stack(s) at that furnace, Fee 6 (SV261-263) *All sources eligible for testing are listed and the ones that will be tested will be dependent upon the process operating availability during the week of December 19, 2005.

PART III. OPERATING CONDITIONS



### The table below includes a summary of the industrial processes and related control equipment.

Process Equipment Description for Units to be tested: 

### EU104, EU114, EU262 — Pellet Indurating Furnaces 11, 12 and 6, controlled by Electrostatic Precipitators (CE104-105, CE114-115, CE261-263)

Process Equipment Parameter Monitoring During Performance Test: 

### EU104, EU114, EU262 — greenball feed rate and fired pellet production rate (long tons/hr), heat input (MMBtu/hr) — natural gas will be fired during the test: maximum rate of 250 long tons/hr for Furnace 11 or Furnace 12, maximum rate of 110 long tons/hr for Furnace 6 Control Equipment Operating Parameter During Test: 

### CE104-105, CE114-115, CE261-263- WWESP are in place for PM and SO2 control, but no controls are present or required for NOx.

PART IV. TEST METHODS



### The following is a description of the number of test runs, length of test runs, and sampling rate for each pollutant. Test methods apply to the proposed sample location.



## A. EPA Method 1 for the location of test ports and traverse points. One determination per test location.

2

### B. EPA Method 2 for stack gas velocity and volumetric flow rate. One determination concurrent with each Method 7E sample test run. One determination will be made on the other Waste Gas stack(s) associated with the furnace being tested.

C. EPA Method 3A to determine stack gas composition and dry molecular weight. Concurrent with each Method 7E test run. The associated waste gas stacks having airflow rates determined, will assume that the gas composition is the same as the stack with the NOx emissions test.

D. EPA Method 4 for the determination of stack gas moisture content. One determination concurrent with each Method 7E test run.

E. EPA Method 7E for the determination of nitrogen oxides. Three 60-minute test runs per test.

PART V. CEMS

There are no CEMS located at the emission points to be tested.

PART VI. OTHER

The NOx determinations will be reported in units of lb/hr and lb/long ton of pellets. The other airflow determination(s) of the other associated waste gas stacks will be reported. The NOx determination on the one waste gas stack will be assumed to be equal to the emissions from the other associated waste gas stacks. The airflow rates on the other associated waste gas stacks are determined to only demonstrate that the airflow rates are similar, within 5% of the stack being tested, and these airflow rates will not used in calculating the NOx emissions.

Testing schedule: Week of January 31

— 

### February 3, 2005

Day Description

Tuesday December 20, 2005 Travel to facility and set up test equipment

Wednesday December 21, 2005 Test (morning) Furnace 11 or 12 Waste Gas Stack (test 1 of 2 stacks at one furnace) Test (afternoon) Furnace 6 Hood Exhaust — Waste Gas Stack (test 1 of 3 stacks) Note: Scheduled test times may change depending on process operating schedule.



### Test Report:

3

### One complete test report (one hard copy) will be submitted within 45 days of the last test performance date. A CDROM copy of the report in *.pdf format (as an alternative to microfiche) will be submitted within 105 days of the last test performance date.

Submittal Address: Mr. Andrew Place Performance Test Coordinator Minnesota Pollution Control Agency 520 Lafayette Road St. Paul, Minnesota 55155-4194

4

# Performance Test Plan Approval

Minnesota

• Pollution

. .
• Control Agency 

## .Minnesota'-PollUtiOn -Centre! A g 

## ency 

## o Lafayette *LINT. Saint Paul; WIN -:515-41.,4. 

## (651)

. 296-6300

. 

## wwv..pea:tate.tnn:us :
, - AQ#27A 

## Facility Name: Northshore Mining 

## Facility Contact: Scott Gischia 

## Address: 10 Outer Drive, Silver Bay, MN 55614 

## Phone: (218) 226-6076 

## ,Emission Unit(s): Furnace 11 or 12 and Furnace 6 

## Scheduled For: December 21, 2005 

## at your Facility located in Silver Bay, 

## Minnesota. Your test plan submitted on December 9, 2005, and discussed on December 15, 2005, has been approved by the Minnesota Pollution Control Agency (1V1PCA) as follows:

• Shortened test notification approved

E Test plan approved without modification 

# 1=1 Test plan approved with the following provisions:

One stack from Furnace 11 or 12 and one stack from Furnace 6 to be tested. Air flows will be calculated determined for all stacks.
Include in the final test report the full reference method data record (strip chart and/or datalogger output) used to calculate emissions. The data record should include calibration values for any instrumental analyzer used for emissions compliance testing.
Normal Operating conditions listed in test plan.


## Attached Forms:

El Operating Data Summary- Combustion Sources Operating Data Summary- Process Sources El Certifications Form Operating Data Summary- Waste Combustors El Operating Data Summary- Asphalt Plants Microfiche/CD-ROM Submittal Form


## Note: Forms are also available at: www.pca.state.mn.us/air/performancetest.html 

## Approved by: Date: 

## December 15, 2005

Andrew Place Performance Test Coordinator Compliance and Enforcement Section Industrial Division 

## Please contact me at (651) 296-7169 if you have any questions regarding this approval. Please be aware that enforcement action will be taken for performance test failures indicating emissions above applicable limits (excess actual emissions to the environment). Failures commonly result in assessment of a monetary penalty. Upon the first test failure, the Company should take immediate measures to minimize emissions. The measures taken should be documented, as they will become part of the record of corrective actions.

### Hard Copy Performance Test Reports and Microfiche or CD Copy submittals will be addressed to: Compliance Tracking Coordinator, Compliance and Enforcement Unit, Industrial Division, Minnesota Pollution Control Agency, 520 Lafayette Road North, St. Paul, Minnesota 55155-4194 cc: Mark Petersen, Barr Engineering, Edina (email) Bob Beresford, MPCA, Duluth (email) AQ Correspondence File No. 27A

# Appendix H
Project Participants

# Project Participants

Northshore Mining Company 

### Scott Gischia — Environmental Engineer

Minnesota Pollution Control Agency 

### Andrew Place — Performance Test Coordinator Bob Beresford — Pollution Control Specialist

Barr Engineering Company 

### Tim Russell — Vice President / Chemical Engineer Mark Petersen — Project Manager Pete Rossmiller — Sr. Air Quality Technician / Team Leader Dan Koschak — Air Quality Technician