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AIR EMISSION PERMIT NO. 06100004- 004 

Major Amendment 

IS ISSUED TO

MINNESOTA POWER DIVISION OF ALLETE INC 

Wisconsin Public Power Inc System 

Minnesota Power Inc - Boswell Energy Ctr 

1210 3rd Street Northwest 

Cohasset, Itasca County, MN 55721 

The emission units, control equipment and emission stacks at the stationary source authorized in 

this permit amendment are as described in the Permit Applications Table. 

This permit amendment supersedes Air Emission Permit No. 06100004-003 and authorizes the 

Permittee to construct the stationary source at the address listed above unless otherwise noted in 

Table A. The Permittee must comply with all the conditions of the permit. Any changes or 

modifications to the stationary source must be performed in compliance with Minn. 

R. 7007.1150 to 7007.1500. Terms used in the permit are as defined in the state air pollution 

control rules unless the term is explicitly defined in the permit. 

Unless otherwise indicated, all the Minnesota rules cited as the origin of the permit terms are 

incorporated into the State Implementation Plan under 40 CFR § 52.1220 and as such are 

enforceable by U.S. Environmental Protection Agency (EPA) Administrator or citizens under the 

Clean Air Act. 

Permit Type: Federal; Pt 70/Major for NSR;

Operating Permit Issue Date: March 28, 2007

Major Amendment Issue Date: August 12, 2009

Expiration Date: 03/28/2012 – Title I Conditions do not expire.

 

 Don Smith, P.E., Manager 

 Air Quality Permits Section 

 Industrial Division 

 

 for Paul Eger 

 Commissioner 

 Minnesota Pollution Control Agency 

Permit Applications Table

Permit Type Application Date Permit 

Action 

Total Facility Operating Permit - Reissuance September 24, 2001 003

Major Amendment June 26, 2008 004 

Major Amendment September 15, 2008 004 

Major Amendment December 3, 2008 004 

Major Amendment September 5, 2008 004 

Reopening January 22, 2009 004 

Reopening October 9, 2008 004 

Reopening June 5, 2008 004 

 

TABLE OF CONTENTS 

Notice to the Permittee 

Permit Shield 

Facility Description 

Amendment Description

Table A: Limits and Other Requirements 

Table B: Submittals 

Appendices 

NOTICE TO THE PERMITTEE: 

Your stationary source may be subject to the requirements of the Minnesota Pollution Control 

Agency’s (MPCA) solid waste, hazardous waste, and water quality programs. If you wish to 

obtain information on these programs, including information on obtaining any required permits, 

please contact the MPCA general information number at: 

 Metro Area 651-296-6300 

 

 Outside Metro Area 1-800-657-3864 

 TTY 651-282-5332 

The rules governing these programs are contained in Minn. R. chs. 7000-7105. Written questions 

may be sent to: Minnesota Pollution Control Agency, 520 Lafayette Road North, St. Paul, 

Minnesota 55155-4194. 

Questions about this air emission permit or about air quality requirements can also be directed to 

the telephone numbers and address listed above. 

PERMIT SHIELD:

Subject to the limitations in Minn. R. 7007.1800, compliance with the conditions of this permit 

shall be deemed compliance with the specific provision of the applicable requirement identified 

in the permit as the basis of each condition. Subject to the limitations of Minn. R. 7007.1800 and 

7017.0100, subp. 2, notwithstanding the conditions of this permit specifying compliance 

practices for applicable requirements, any person (including the Permittee) may also use other 

credible evidence to establish compliance or noncompliance with applicable requirements. 
FACILITY DESCRIPTION: 

The Boswell Energy Center (facility) is a coal-fired electric utility steam generating plant. 

Emission units at the facility include four power boilers, emergency engine generators, and fuel, 

additive and ash handling equipment. The main fuel for all boilers is sub bituminous coal. They 

may also burn distillate oil, limited amounts of boiler cleaning agents, used oil, oily coal, oily 

paper-based floor dry, wastewater treatment plant sludge, and oily materials (earth substrate with 

petroleum product). Emissions are controlled by baghouses, over fire air, selective Non-Catalytic 

Reduction on Boilers 1 and 2. Low Nitrogen Oxide (NOX) burners, over fire air, selective 

catalytic reduction, baghouse filter a wet scrubber on Boiler 3, and a wet venturi scrubber / 

electrostatic precipitator, and sulfur dioxide spray towers on Boiler 4. 

AMENDMENT DESCRIPTION:

This permit amendment authorizes installation of natural gas fired igniters/heat guns on all boilers; 

EU001, EU002, EU003, and EU004. All boilers currently have a set of oil-fired igniter/heat guns. 

A Prevention of Significant Deterioration (PSD) analysis was conducted for Carbon Monoxide 

(CO) and Volatile Organic Compounds (VOC). A CO limit across the four boilers will be used to 

avoid a significant increase in CO. 

This permit amendment revises the size of emergency generator (EU 023) from 100 kW to 

300 kW. This emergency generator unit (EGU) is part of the retrofitting project for EU003, 

permit No. 06100004-003 issued March 28, 2007. The EGU is to provide power for safe shutdown 

of pollution control equipment during power outages. The original generator has not yet been 

installed. The original project was subject to PSD for CO. Because of the increase in CO emission 

due to the larger EGU the facility has submitted a revised PSD analysis for CO. This includes 

updated Best Available Control Technology and CO air dispersion modeling. 

This permit amendment includes installation of new Continuous Emissions Monitors Systems. 

This would allow the facility to separately monitor the Nitrogen Oxides (NOX), Sulfur Oxides 

(SOX), Carbon Dioxide, Opacity, and Air Flow for EU001, EU002, and EU003. This change does 

not involve any emissions increases or change to emission permit limits. 

This permit action incorporates multiply minor amendments and reopenings initiated by the 

MPCA. These are the incorporated Reopenings; Certified MR 040 to replace MR 005 for 

monitoring opacity for EU004, Certified MR 041 to replace MR 023 for monitoring air flow for 

EU004, March 21, 2008, letter from Jeff Smith to Minnesota Power. This permit incorporates the 

requirements that stem from Title V modeling that was done by the permittee. This permit also 

incorporates a propane fired slag shock system. This system qualifies as an insignificant 

modification due to emissions. The system will be installed to target tougher-to-remove slag 

deposits by using the percussion of a small controlled explosion to shock the deposits off of the 

boiler. Since the system will operate within the boiler propane has to be added to the allowable 

fuels list for all boilers at the facility. This permit amends the maximum achievable operating 

rates for boilers 3 and 4 (EU003, EU004). These updates stem from recent stack tests. This 

amendment corrects allowable fuel for emergency generator 1 (EU007). 
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-1

Table A contains limits and other requirements with which your facility must comply. The limits are located in the first column of

the table (What To do). The limits can be emission limits or operational limits. This column also contains the actions that you must

take and the records you must keep to show that you are complying with the limits. The second column of Table A (Why to do it)

lists the regulatory basis for these limits. Appendices included as conditions of your permit are listed in Table A under total facility

requirements.

Subject Item: Total Facility

What to do Why to do it

DETERMINING IF A PROJECT/MODIFICATION IS SUBJECT TO NEW SOURCE

REVIEW

hdr

These requirements apply if a reasonable possibility (RP) as defined in 40 CFR

Section 52.21(r)(6)(vi) exists that a proposed project, analyzed using the

actual-to-projected-actual (ATPA) test (either by itself or as part of the hybrid test at

Section 52.21(a)(2)(iv)(f)) and found to not be part of a major modification, may

result in a significant emissions increase (SEI). If the ATPA test is not used for the

project, or if there is no RP that the proposed project could result in a SEI, these

requirements do not apply to that project. The Permittee is only subject to the

Preconstruction Documentation requirement for a project where a RP occurs only

within the meaning of Section 52.2(r)(6)(vi)(a).

Even though a particular modification is not subject to New Source Review (NSR),

or where there isn't a RP that a proposed project could result in a SEI, a permit

amendment, recordkeeping, or notification may still be required by Minn. R.

7007.1150 - 7007.1500.

Title I Condition: 40 CFR Section 52.21(r)(6); Minn. R.

7007.3000; Minn. R. 7007.0800, subp. 2

Preconstruction Documentation -- Before beginning actual construction on a

project, the Permittee shall document the following:

1. Project description

2. Identification of any emission unit (EU) whose emissions of an NSR pollutant

could be affected

3. Pre-change potential emissions of any affected existing EU, and the projected

post-change potential emissions of any affected existing or new EU.

4. A description of the applicability test used to determine that the project is not a

major modification for any regulated NSR pollutant, including the baseline actual

emissions, the projected actual emissions, the amount of emissions excluded due

to increases not associated with the modification and that the EU could have

accommodated during the baseline period, an explanation of why the amounts

were excluded, and any creditable contemporaneous increases and decreases that

were considered in the determination.

The Permittee shall maintain records of this documentation.

Title I Condition: 40 CFR Section 52.21(r)(6); Minn. R.

7007.3000; Minn. R. 7007.1200, subp. 4; Minn. R.

7007.0800, subps. 4 & 5

The Permittee shall monitor the actual emissions of any regulated NSR pollutant

that could increase as a result of the project and that were analyzed using the

ATPA test, and the potential emissions of any regulated NSR pollutant that could

increase as a result of the project and that were analyzed using potential emissions

in the hybrid test. The Permittee shall calculate and maintain a record of the sum of

the actual and potential (if the hybrid test was used in the analysis) emissions of the

regulated pollutant, in tons per year on a calendar year basis, for a period of 5

years following resumption of regular operations after the change, or for a period of

10 years following resumption of regular operations after the change if the project

increases the design capacity of or potential to emit of any unit associated with the

project.

Title I Condition: 40 CFR Section 52.21(r)(6); Minn. R.

7007.3000; Minn. R. 7007.0800, subps. 4 & 5

Before beginning actual construction of any project which includes any electric

utility steam generating unit (EUSGU), the Permittee shall submit a copy of the

preconstruction documentation (items 1-4 under Preconstruction Documentation,

above) to the Agency.

Title I Condition: 40 CFR Section 52.21(r)(6)(ii) and

Minn. R. 7007.3000; Minn. R. 7007.0800, subp. 4 & 5

For any project which includes any EUSGU, the Permittee must submit an annual

report to the Agency, within 60 days after the end of the calendar year. The report

shall contain:

a. The name and ID number of the facility, and the name and telephone number of

the facility contact person

b. The quantified annual emissions analyzed using the ATPA test, plus the

potential emissions associated with the same project analyzed as part of a hybrid

test.

c. Any other information, such as an explanation as to why the summed emissions

differ from the preconstruction projection, if that is the case.

Title I Condition: 40 CFR Section 52.21(r)(6) and Minn.

R. 7007.3000; Minn. R. 7007.0800, subp. 4 & 5
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-2

For any project which does not include any EUSGU, the Permittee must submit a

report to the Agency if the annual summed (actual, plus potential used in hybrid

test) emissions differ from the preconstruction projection and exceed the baseline

actual emissions by a significant amount as listed at 40 CFR Section 52.21(b)(23).

Such report shall be submitted to the Agency within 60 days after the end of the

year in which the exceedances occur. The report shall contain:

a. The name and ID number of the facility, and the name and telephone number of

the facility contact person

b. The annual emissions (actual, plus potential if any part of the project was

analyzed using the hybrid test) for each pollutant for which the preconstruction

projection and significant emissions rate is exceeded.

c. Any other information, such as an explanation as to why the summed emissions

differ from the preconstruction projection.

Title I Condition: 40 CFR Section 52.21(r)(6) and Minn.

R. 7007.3000; Minn. R. 7007.0800, subp. 4 & 5

OPERATIONAL REQUIREMENTS hdr

Circumvention: Do not install or use a device or means that conceals or dilutes

emissions, which would otherwise violate a federal or state air pollution control rule,

without reducing the total amount of pollutant emitted.

Minn. R. 7011.0020

Air Pollution Control Equipment: Operate all pollution control equipment whenever

the corresponding process equipment and emission units are operated, unless

otherwise noted in Table A.

Minn. R. 7007.0800, subp. 2; Minn. R. 7007.0800,

subp. 16(J)

Operation and Maintenance Plan: Retain at the stationary source an operation and

maintenance plan for all air pollution control equipment. At a minimum, the O & M

plan shall identify all air pollution control equipment and control practices and shall

include a preventative maintenance program for the equipment and practices, a

description of (the minimum but not necessarily the only) corrective actions to be

taken to restore the equipment and practices to proper operation to meet applicable

permit conditions, a description of the employee training program for proper

operation and maintenance of the control equipment and practices, and the records

kept to demonstrate plan implementation.

Minn. R. 7007.0800, subp. 14 and Minn. R. 7007.0800,

subp. 16(J)

Fugitive Emissions: Do not cause or permit the handling, use, transporting, or

storage of any material in a manner which may allow avoidable amounts of

particulate matter to become airborne. Comply with all other requirements listed in

Minn. R. 7011.0150.

Minn. R. 7011.0150

Noise: The Permittee shall comply with the noise standards set forth in Minn. R.

7030.0010 to 7030.0080 at all times during the operation of any emission units.

This is a state requirement only and is not federally enforceable.

Minn. R. 7030.0010-7030.0080

Inspections: Upon presentation of credentials and other documents as may be

required by law, allow the Agency, or its representative, to enter the Permittee's

premises, to have access to and copy any records required by this permit, to

inspect at reasonable times (which include any time the source is operating) any

facilities, equipment, practices or operations, and to sample or monitor any

substances or parameters at any location. The Permittee may require that MPCA

inspectors be accompanied by MP staff during the inspection. Permittee's staff

shall be available whenever the plant is operating.

Minn. R. 7007.0800, subp. 9(A)

Comply with general conditions listed in Minn. R. 7007.0800, subp. 16. Minn. R. 7007.0800, subp. 16

Comply with Fugitive Emissions Control Plan: Follow the actions and record

keeping specified in the control plan. The plan may be amended with the

Commissioner's approval. If the Commissioner determines that you are out of

compliance with Minn. R. 7011.0150 or the control plan, then you may be required

to amend the control plan and/or install and operate particulate matter ambient

monitors.

Minn. Stat. Section 116.07, subd. 4a; Minn. R.

7007.0100; Minn. R. 7007.0800, subp. 2; Minn. R.

7011.0150; Minn. R. 7009.0020

Oily Floor Dry: Limit combustion to: 1) cellulose based only, 2) 25 tons per year,

and 3) 1.25 tons per hour.

Title I Condition: To avoid classification as a major

modification under 40 CFR Section 52.21and Minn. R.

7007.3000

The following does not apply to Boilers No. 001, 002, 003, and 004. These units

contain specific operating and/or production limits requirements.

Operating and/or production limits will be placed on emission units based on

operating conditions during compliance testing. Limits set as a result of a

compliance test (conducted before or after permit issuance) apply until new

operating/production limits are set following formal review of a performance test as

specified by Minn. R. 7017.2025.

Minn. R. 7017.2025

PERFORMANCE TESTING hdr
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-3

Performance Test Notifications and Submittals:

Performance Tests are due as outlined in Tables A and B of the permit. See Table

B for additional testing requirements.

Performance Test Notification (written): due 30 days before each Performance Test

Performance Test Plan: due 30 days before each Performance Test

Performance Test Pre-test Meeting: due 7 days before each Performance Test

Performance Test Report: due 45 days after each Performance Test

Performance Test Report - Microfiche Copy: due 105 days after each Performance

Test

The Notification, Test Plan, and Test Report may be submitted in alternative format

as allowed by Minn. R. 7017.2018.

Minn. R. 7017.2030, subp. 1-4, 7017.2018 and Minn.

R. 7017.2035, subp. 1-2

Performance Testing: Conduct all performance tests in accordance with Minn. R.

ch. 7017 unless otherwise noted in Tables A, B, and/or C.

Minn. R. ch. 7017

MONITORING REQUIREMENTS hdr

Monitoring Equipment Calibration: Annually calibrate all required monitoring

equipment (any requirements applying to continuous emission monitors are listed

separately in this permit).

Minn. R. 7007.0800, subp. 4(D)

Operation of Monitoring Equipment: Unless otherwise noted in Tables A, B, and/or

C, monitoring a process or control equipment connected to that process is not

necessary during periods when the process is shutdown, or during checks of the

monitoring systems, such as calibration checks and zero and span adjustments. If

monitoring records are required, they should reflect any such periods of process

shutdown or checks of the monitoring system.

Minn. R. 7007.0800, subp. 4(D)

RECORDKEEPING hdr

Recordkeeping: Maintain records describing any insignificant modifications (as

required by Minn. R. 7007.1250, subp. 3) or changes contravening permit terms (as

required by Minn. R. 7007.1350, subp. 2), including records of the emissions

resulting from those changes.

Minn. R. 7007.0800, subp. 5(B)

Recordkeeping: Retain all records at the stationary source for a period of five (5)

years from the date of monitoring, sample, measurement, or report. Records which

must be retained at this location include all calibration and maintenance records, all

original strip-chart recordings for continuous monitoring instrumentation, and copies

of all reports required by the permit. Records must conform to the requirements

listed in Minn. R. 7007.0800, subp. 5(A).

Minn. R. 7007.0800, subp. 5(C)

REPORTING HDR

Application for Permit Amendment: If you need a permit amendment, submit

application in accordance with the requirements of Minn. R. 7007.1150 through

Minn. R. 7007.1500. Submittal dates vary, depending on the type of amendment

needed.

Minn. R. 7007.1150 through Minn. R. 7007.1500

Notification of Deviations Endangering Human Health or the Environment: As soon

as possible after discovery, notify the Commissioner or the state duty officer, either

orally or by facsimile, of any deviation from permit conditions which could endanger

human health or the environment.

Minn. R. 7019.1000, subp. 1

Notification of Deviations Endangering Human Health or the Environment Report:

Within 2 working days of discovery, notify the Commissioner in writing of any

deviation from permit conditions which could endanger human health or the

environment. Include the following information in this written description:

1. the cause of the deviation;

2. the exact dates of the period of the deviation, if the deviation has been corrected;

3. whether or not the deviation has been corrected;

4. the anticipated time by which the deviation is expected to be corrected, if not yet

corrected; and

5. steps taken or planned to reduce, eliminate, and prevent reoccurrence of the

deviation.

Minn. R. 7019.1000 subp. 1

Shutdown Notifications: Notify the Commissioner at least 24 hours in advance of a

planned shutdown of any control equipment or process equipment if the shutdown

would cause any increase in the emissions of any regulated air pollutant. If the

owner or operator does not have advance knowledge of the shutdown, notification

shall be made to the Commissioner as soon as possible after the shutdown.

However, notification is not required in the circumstances outlined in Items A, B

and C of Minn. R. 7019.1000, subp. 3.

At the time of notification, the owner or operator shall inform the Commissioner of

the cause of the shutdown and the estimated duration. The owner or operator shall

notify the Commissioner when the shutdown is over.

Minn. R. 7019.1000, subp. 3
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-4

Breakdown Notifications: Notify the Commissioner within 24 hours of a breakdown

of more than one hour duration of any control equipment or process equipment if

the breakdown causes any increase in the emissions of any regulated air pollutant.

The 24-hour time period starts when the breakdown was discovered or reasonably

should have been discovered by the owner or operator. However, notification is not

required in the circumstances outlined in Items A, B and C of Minn. R. 7019.1000,

subp. 2.

At the time of notification or as soon as possible thereafter, the owner or operator

shall inform the Commissioner of the cause of the breakdown and the estimated

duration. The owner or operator shall notify the Commissioner when the

breakdown is over.

Minn. R. 7019.1000, subp. 2

Shutdown and Breakdown Reporting Requirement for the Dust Collector Systems

for Material Handling Equipment: Shutdowns and breakdowns shall be reported on

a quarterly basis to the Agency. The quarterly report shall include an identification

of the dust collector that broke down or was shutdown, the time and reason for the

breakdown or shutdown, a description of any repairs made, and the date and time

the dust collector was placed back in service.

Minn. R. 7019.1000, subp. 2

Emission Inventory Report: due on or before April 1 of each calendar year

following permit issuance. To be submitted on a form approved by the

Commissioner.

Minn. R. 7019.3000 through Minn. R. 7019.3100

Emission Fees: due 60 days after receipt of an MPCA bill Minn. R. 7002.0005 through Minn. R. 7002.0095

Extension Requests: The permittee may apply for an Administrative Amendment to

extend a deadline in a permit by no more than 120 days, provided the proposed

deadline extension meets the requirements of Minn. R. 7007.1400, subp. 1(H).

Minn. R. 7007.1400, subp. 1(H)

ACID RAIN PROGRAM REQUIREMENTS hdr

Emissions from the stationary source cannot exceed any allowances that the

source lawfully holds under federal acid rain regulations, except as allowed by

Minn. R. 7007.0800, subp. 7.

Minn. R. 7007.0800, subp. 7

Acid Rain Certification Report: due 60 days after end of each calendar year. 40 CFR Section 72.90(b) and 40 CFR Section 72.90(c)

If the unit has excess emissions, the designated representative shall submit a

proposed offset plan in accordance with 40 CFR Section 72.9(e).

40 CFR Section 72.9(e)

Keep the certificate of representation, all emissions monitoring information, copies

of all reports, compliance certifications and related submissions and all records

made or required under the Acid Rain Program on site for a period of 5 years from

the date the document was created.

40 CFR Section 72.9(f)

Hold allowances as of the allowance transfer deadline, in the facility's compliance

account. Allowances may not be less than the total annual emissions of sulfur

dioxide from the previous calendar year from the facility.

40 CFR Section 72.9(c)

DISPERSION MODELING REQUIREMENTS hdr

The Permittee shall comply with National Primary and Secondary Ambient Air

Quality Standards, 40 CFR pt. 50, and the Minnesota Ambient Air Quality

Standards, Minn. R. 7009.0010 to 7009.0080. Compliance shall be demonstrated

upon written request by the MPCA.

40 CFR pt. 50; Minn. Stat. Sec. 116.07, subds. 4a and

9; Minn. R. 7007.0100, subps. 7A, 7L and 7M; Minn. R.

7007.0800, subps. 1, 2, and 4; Minn. R.

7009.0010-7009.0080

The parameters used in SO2, PM10, CO modeling 06100004-004 are listed in

Appendix B of this permit.

Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R.

7009.0020; Minn. R. 7007.0100; Minn. R. 7007.0800,

subp. 2

The parameters used in NOx modeling 06100004-004 are listed in Appendix B of

this permit.

Modeling Triggers: For changes that do not require a permit amendment or that

require a minor permit amendment, and that affect any modeled parameter or

emission rate, a Remodeling Submittal requirement is not triggered. The Permittee

shall keep updated records on site of all parameters and emission rates. The

Permittee shall submit any changes to parameters and emission rates with the next

required remodeling submittal.

For changes that require a moderate or major permit amendment and affect any

modeled parameter or increase in an emission rate, a Remodeling Submittal

requirement is triggered. The Permittee shall include previously made changes to

parameters and emission rates that did not trigger a remodeling submittal with this

modeling submittal.

Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R.

7009.0020; Minn. R. 7007.0100; Minn. R. 7007.0800,

subp. 2
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-5

Remodeling Submittal: The Permittee must submit to the Commissioner for

approval changes meeting the above criteria and must wait for a written approval

(in the form of an issued permit amendment) before making such changes. The

information submitted must include, for stack and vent sources, source emission

rate, location, height, diameters, exit velocity, exit temperature, discharge direction,

use of rain caps or rain hats, and, if applicable, locations and dimensions of nearby

buildings. For non-stack/vent sources, this includes the source emission rate,

location, size and shape, release height, and, if applicable, any emissions rate

scalars, and the initial lateral dimensions and initial vertical dimensions and

adjacent building heights.

Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R.

7009.0020; Minn. R. 7007.0100; Minn. R. 7007.0800,

subp. 2

(continued)

The plume dispersion characteristics due to the revisions of the information must

be equivalent to or better than the latest dispersion characteristics modeled. The

Permittee shall demonstrate this equivalency in the proposal. If the information

does not demonstrate equivalent or better dispersion characteristics, or if a

conclusion cannot readily be made about the dispersion, the Permittee must submit

full remodeling.

Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R.

7009.0020; Minn. R. 7007.0100; Minn. R. 7007.0800,

subp. 2

CLEAN AIR INTERSTATE RULE hdr

At the present time, the permittee must comply with all the applicable requirements

in 40 CFR pt. 97 for a CAIR NOx source, a CAIR SO2 source, a CAIR NOx unit,

and a CAIR SO2 unit as defined in 40 CFR Sections 97.102 and 97.202.

If the US Environmental Protection Agency promulgates a rule to stay 40 CFR pt.

97 in Minnesota, this requirement will be of no further force and effect upon the

effective date of the rule.

40 CFR pt. 97; 40 CFR Section 52.1240; Minn. R.

7007. 0800, subp. 2.

Oil & Natural Gas Carbon Monoxide Emissions Limit hdr

Carbon Monoxide: less than or equal to 319 tons/year using 12-month Rolling Sum .

This limit was taken to avoid a Air Emissions Increase Analysis when installing

natural gas igniter/heat guns. This limit is derived from limited potential to emit

increase of 95 tons/yr of CO.

Combined CO emissions from oil and natural gas combustion used in all igniters

and warm-up guns in EU 001, EU 002, EU 003, and EU 004 shall not exceed 319

tons per year of CO. This excludes CO emissions from coal combustion and other

permitted fuels. This limit applies on a 12-month rolling sum basis and must be

evaluated monthly. The 12-month rolling sum becomes effective at the end of the

12th calendar month following issuance of permit 06100004-004. The following

emission factors shall be used: Fuel Oil - 5 lbs CO/1000 gallons; Natural Gas - 84

lbs CO/million cubic feet.

Minn. R. 7007.0800 subp. 2

Recordkeeping: evaluate 12-month rolling sum of Carbon Monoxide on a monthly

basis.

Minn. R. 7007.0800 subp. 5
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-6

Subject Item: GP 002 Opacity Monitors

Associated Items: MR 020 Blr 1 Opacity

MR 021 Blr 2 Opacity

MR 027 Boiler 3 Opacity

MR 040 Blr 4 Opacity

What to do Why to do it

CONTINUOUS OPACITY MONITORING SYSTEMS (COMS) Requirements

(Additional requirements are located under the associated MR subject items and in

Table B)

hdr

All COMS shall complete a minimum of one cycle of sampling and analyzing for

each successive 10-second period and one cycle of data for each successive

6-minute period.

Minn. R. 7017.1200, subp. 1, 2 & 3; 40 CFR Section

60.13(e)(1); 40 CFR Section 60.13(h)

Continuous Operation: COMS must be operated and data recorded during all

periods of emission unit operation including periods of emission unit start-up,

shutdown, or malfunction except for periods of acceptable monitor downtime. This

requirement applies whether or not a numerical emission limit applies during these

periods. A COMS must not be bypassed except in emergencies where failure to

bypass would endanger human health, safety, or plant equipment.

Acceptable monitor downtime includes reasonable periods as listed in Items A, B,

C and D of Minn. R. 7017.1090, subp. 2.

Minn. R. 7017.1090, subp. 1; 40 CFR Section 60.13(e)

COMS QA/QC: The owner or operator of an affected facility is subject to the

performance specifications listed in 40 CFR pt. 60, Appendix B and shall operate,

calibrate, and maintain each COMS according to the QA/QC procedures in Minn.

R. 7017.1210.

40 CFR Section 60.13(a); Minn. R. 7017.1210

COMS Daily Calibration Drift Check: The Permittee must automatically, intrinsic to

the opacity monitor, check the zero and upscale (span) calibration drifts at least

once daily. The acceptable range is as defined in 40 CFR pt. 60, Appendix B, PS-1.

The optical surfaces shall be cleaned when the cumulative automatic zero

compensation exceeds 4 percent opacity. Minimum procedures must include an

automated method for producing a simulated zero opacity condition and an upscale

opacity condition as specified in 40 CFR 60.13(d)(2).

Minn. R. 7017.1210, subp. 2; 40 CFR Section

60.13(d)(l) regarding COMS and 60.13(d)(2)

Attenuator Calibration: The Permittee shall have an independent testing company

conduct calibrations of each of the neutral density filters used in the calibration

error audit according to the procedure in Code of Federal Regulations, Title 40,

Part 60, Appendix B, Section 7.1.3.1 within the time frame of opacity stability

guaranteed by the attenuator manufacturer. The manufacturer's guarantee of

stability shall be on site available for inspection.

Minn. R. 7017.1210, subp. 4

Recordkeeping: The owner or operator must retain records of all COMS monitoring

data and support information for a period of five years from the date of the

monitoring sample, measurement or report. Records shall be kept at the source.

Minn. R. 7017.1130
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-7

Subject Item: GP 003 NOx and SO2 Monitors

Associated Items: MR 002 Blr 1, 2, and 3 SO2

MR 004 Blr 1 and 2 NOx

MR 007 Blr 4 SO2

MR 008 Blr 4 NOx

MR 016 Blr 3 NOx

MR 028 Blr 1 SO2

MR 029 Blr 1 NOx

MR 032 Blr 2 SO2

MR 033 Blr 2 NOx

MR 036 Blr 3 SO2

MR 037 Blr 3 NOx

What to do Why to do it

CONTINUOUS EMISSION MONITORING SYSTEMS (CEMS) Requirements

(Additional requirements are located under the associated MR subject items and in

Table B)

hdr

CEMS QA/QC: The owner or operator of an affected facility shall operate,

calibrate, and maintain each CEMS according to the QA/QC procedures in 40 CFR

pt. 75, appendix B as amended.

40 CFR Section 75.21

Daily Calibration error (CE) Test: conduct daily CE testing on all CEMS required by

the Acid Rain Program, in accordance with 40 CFR pt. 75, appendix B.

40 CFR pt. 75, Appendix B, section 2.1

Relative Accuracy Test Audit (RATA) Notification: due 30 days before CEMS

Relative Accuracy Test Audit (RATA)).

Minn. R. 7017.1180, subp. 2

Recordkeeping: The owner or operator must retain records of all CEMS monitoring

data and support information for a period of five years from the date of the

monitoring sample, measurement or report. Records shall be kept at the source.

Minn. R. 7017.1130; and 40 CFR Part 75, Subpart F

Continuous Operation: CEMS must be operated and data recorded during all

periods of emission unit operation including periods of emission unit start-up,

shutdown, or malfunction except for periods of acceptable monitor downtime. This

requirement applies whether or not a numerical emission limit applies during these

periods. A CEMS must not be bypassed except in emergencies where failure to

bypass would endanger human health, safety, or plant equipment.

40 CFR Section 60.13(e); Minn. R. 7017.1090

ALTERNATIVE OPERATING SCENARIOS hdr

Operating Scenario 1: Use MR 002, MR 004, and MR 016 to continuously monitor

emissions for SO2 and NOx from EU 001, EU 002, and EU 003. This scenario

applies until EU 003 is shut down to tie in the new pollution control retrofit

equipment permitted in 06100004-003.

Operating Scenario 2: Use MR 028, MR 032, and MR 036 to continuously monitor

SO2 emissions from EU 001, EU 002, and EU 003. Use MR 029, MR 033, and MR

037 to continuously monitor NOx emissions from EU 001, EU 002, and EU 003.

Requirements for MR 002, MR 004, and MR 016 no longer apply. This scenario will

apply to EU 001 and EU 002 immediately at the time EU 003 is shut down to tie in

the new pollution control retrofit equipment. Operating Scenario 2 will apply to

EU003 once the unit is returned to service. Operating Scenario 1 will no longer

apply once Operating Scenario 2 becomes effective.

Minn. R. 7007.0800, subp. 4, 5 & 6
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-8

Subject Item: GP 004 Boilers 1-4 Sulfur Dioxide Limits

Associated Items: EU 001 Power Boiler 1 

EU 002 Power Boiler 2 

EU 003 Power Boiler 3

EU 004 Power Boiler 4

What to do Why to do it

BOILER 3 AND 4 COMBINED LIMITS hdr

When EU 001 and EU 002 are not operating, sulfur dioxide emissions are limited to

less than or equal to the following:

Condition 1) 3.52 lb/mmBtu for SV 003 and 1.2 lb/mmBtu for SV 004, both on a

one-hour average; OR,

Condition 2) 4.0 lb/mmBtu for SV 003 and 0.88 lb/mmBtu for SV 004, both on a

one-hour average; OR,

Condition 3) 3.67 lb/mmBtu for SV 003 and 1.10 lb/mmBtu for SV 004, both on a

one-hour average.

Minn. R. ch. 7009; 40 CFR pt. 50

BOILER 1 EMISSION LIMITS hdr

When the EU 001 flue gasses are vented through SV 001:

 Sulfur Dioxide: less than or equal to 1.18 lbs/million BTU heat input using 1 Hour

Average

Minn. R. 7009.0020

Sulfur Dioxide: less than or equal to 4.0 lbs/million Btu heat input using 1-Hour

Average and a 3-Hour Average for solid fuels, and 2.0 lbs/mmBtu when burning

liquid fuels. When solid and liquid fossil fuels are burned simultaneously in any

combination, the applicable standard shall be determined by proration using the

following formula: w=[2y+4z]/(y+z) where y is the % heat input from liquid fossil fuel

and z is the % heat from solid fuels. This limit applies only when EU001 is vented

through SV003.

Minn. R. 7011.0510, subp. 1

Minn. R. 7009

BOILER 2 EMISSION LIMITS hdr

When EU 002 flue gasses are vented through SV 001.

 Sulfur Dioxide: less than or equal to 1.18 lbs/million Btu heat input using 1-Hour

Average

Minn. R. 7009.0020

Sulfur Dioxide: less than or equal to 4.0 lbs/million Btu heat input using 1-Hour

Average and a 3-Hour Average for solid fuels, and 2.0 lbs/mmBtu when burning

liquid fuels. When liquid and solid fossil fuels are burned simultaneously in any

combination, the applicable standard shall be determined by proration using the

following formula: w=[2y+4z]/(y+z) where y is the % heat input from liquid fossil fuel

and z is the % heat from solid fuels. This limit applies only when EU 002 is vented

through SV 003.

Minn. R. 7011.0510, subp. 1

Minn. R. 7009

BOILER 3 LIMITS hdr

Sulfur Dioxide: less than or equal to 2.97 lbs/million Btu heat input using 1-Hour

Average when EU 001 and EU 002 are operating, and the EU 001 and EU 002

emissions are vented through SV 001.

Minn. R. 7009.0020

Sulfur Dioxide: less than or equal to 0.09 lbs/million Btu heat input based on a

30-day rolling average. This limit does not apply during times of startup, shutdown

or malfunction. (Boiler 3 limit). This limit applies regardless of the operation and

venting of the other boilers.

This limit applies after return to regular operation of Unit 3 following modification of

the boiler and its pollution control equipment stream.

Minn. R. 7007.0800, subp. 2

Sulfur Dioxide: less than or equal to 4.0 lbs/million Btu heat input using 1-Hour

Average and a 3-Hour Average for solid fuels, and 2.0 lbs/mmBtu when burning

liquid fuels. When solid and liquid fossil fuels are burned simultaneously in any

combination, the applicable standard shall be determined by proration using the

following formula: w=[2y+4z]/(y+z) where y is the % heat input from liquid fossil fuel

and z is the % heat from solid fuels. The EU003 sulfur dioxide limit applies

regardless if EU001 and EU002 are operating.

Minn. R. 7011.0510, subp. 1

Minn. R. 7009

BOILER 4 EMISSION LIMITS hdr
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-9

Sulfur Dioxide: less than or equal to 1.2 lbs/million Btu heat input using 1-Hour

Average period for solid fossil fuel, and 0.8 lb/million BTU using 1 Hour Average

period for liquid fossil fuel. When solid and liquid fossil fuels are burned

simultaneously in any combination, the applicable standard shall be determined by

proration using the following formula: w=[0.8y+1.2z]/(y+z) where y is the % heat

input from liquid fossil fuel and z is the % heat from solid fuels.

Title I Condition: 40 CFR Section 52.21(j) PSD BACT

limit and ambient impacts analysis; 40 CFR Section

60.43

Sulfur Dioxide: less than or equal to 0.33 lbs/million Btu heat input based on an

annual average.

Minn. R. 7021.0050, subp. 5
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-10

Subject Item: GP 005 Low Temperature Fabric Filters

Associated Items: CE 007 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

CE 008 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

CE 009 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

CE 010 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

CE 013 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

CE 015 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

CE 016 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

CE 017 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

CE 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

What to do Why to do it

The Permittee shall operate and maintain the control equipment such that it

achieves an overall control efficiency for Total Particulate Matter: greater than or

equal to 99 percent control efficiency

Minn. R. 7007.0800, subp. 2 and 14

The Permittee shall operate and maintain the fabric filter at all times that any

emission unit controlled by the fabric filter is in operation. The Permittee shall

document periods of non-operation of the control equipment.

Minn. R. 7007.0800, subp. 2 and 14

Visible Emissions: The Permittee shall check the fabric filter stacks for any visible

emissions once each day of operation during daylight hours.

Minn. R. 7007.0800, subp. 4 and 5

The Permittee shall operate and maintain the fabric filter in accordance with the

Operation and Maintenance (O & M) Plan. The Permittee shall keep copies of the

O & M Plan available onsite for use by staff and MPCA staff.

Minn. R. 7007.0800, subp. 14

Corrective Actions: The Permittee shall take corrective action as soon as possible if

any of the following occur:

- visible emissions are observed; or

- the fabric filter or any of its components are found during the inspections to need

repair.

Corrective actions shall eliminate visible emissions, and/or include completion of

necessary repairs identified during the inspection, as applicable. Corrective actions

include, but are not limited to, those outlined in the O & M Plan for the fabric filter.

The Permittee shall keep a record of the type and date of any corrective action

taken for each filter.

Minn. R. 7007.0800, subp. 4, 5, and 14

Periodic Inspections: At least once per calendar quarter, or more frequently as

required by the manufacturing specifications, the Permittee shall inspect the control

equipment components. The Permittee shall maintain a written record of these

inspections.

Minn. R. 7007.0800, subp. 4, 5 and 14
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-11

Subject Item: EU 001 Power Boiler 1 

Associated Items: CE 001 Fabric Filter - High Temperature, i.e., T>250 Degrees F

GP 004 Boilers 1-4 Sulfur Dioxide Limits

MR 002 Blr 1, 2, and 3 SO2

MR 003 Blr 1, 2, and 3 CO2

MR 004 Blr 1 and 2 NOx

MR 020 Blr 1 Opacity

MR 028 Blr 1 SO2

MR 029 Blr 1 NOx

MR 030 Blr 1 CO2

MR 031 Blr 1 Air Flow

SV 001 

SV 003 

What to do Why to do it

EMISSION LIMITS hdr

Total Particulate Matter: less than or equal to 0.1 lbs/million BTU heat input Title I condition: 40 CFR Section 52.21(k) (ambient air

impacts analysis); also meets the requirements of

Minn. R. 7011.0510, subp. 1

Opacity: less than or equal to 20 percent opacity using 6-minute Average except for

one six-minute period per hour of not more than 60 percent opacity.

Minn. R. 7011.0510, subp. 2

See GP004 for sulfur dioxide limits. hdr

Comply with the applicable Acid Rain emissions limitation for sulfur dioxide. 40 CFR Section 72.9(c)(1)(ii), 40 CFR Section

72.9(g)(4)

NOx Averaging Plan

Maintain an annual average NOx emission rate of 0.46 lbs/MMBtu and limit the

annual heat input to less than or equal to 3,500,000 mmBtu per year.

 OR

Maintain a Btu-weighted annual average emission rate in lbs/mmBtu, averaged

over the units specified in the NOx averaging plan, that is less than or equal to the

Btu-weighted annual average emission rate averaged over the same units had they

each been operated during the same period of time in compliance with the

applicable emission limitations in 40 CFR Sections 76.5, 76.6, or 76.7. Units

covered in the plan are:

Plant Boiler ID#

Clay Boswell 1, 2, 3, 4

Syl Laskin 1, 2

Taconite Harbor 1, 2, 3

40 CFR Section 76.11

Minn. R. 7011.0553

OPERATIONAL LIMITS AND REQUIREMENTS hdr

Fuel use: limited to sub-bituminous coal, boiler cleaning agents, distillate oil, oily

coal, used oil, oily paper-based floor dry, pipeline quality nature gas, and propane.

Minn. R. 7007.0800, subp. 2

Boiler cleaning agents limited to: EDTA type and Ammonium Bromate, are

generated on-site, 5% of total mass input, oxygen limited to 3% or greater, agents

may only be burned while the boiler is operating at 75 percent of rated capacity or

greater.

Minn. R. 7007.0800, subp. 2

Burn off-specification and on-specification used oil in accordance with Minn. R. ch.

7045, not to exceed 17.5% of rated heat input on an hourly basis (equal to 963

gallons/hr.).

Minn. R. 7007.0800, subp. 2
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-12

Vent all emissions to a fabric filter that meets the requirements of CE001 for

particulate matter control when burning coal. The fabric filter may be bypassed

during startup.

Bypassing of the fabric filter shall be for as short a time as is practicable while

avoiding damage to the fabric filter and it components, but shall not exceed 8 hours.

Title I Condition: control of particulate emissions.

CONTINUOUS MONITORING REQUIREMENTS hdr

The owner or operator shall measure opacity, and all SO2, NOx, and CO2

emissions from affected units in accordance with 40 CFR Section 75.10. See

GP002 for requirements regarding opacity monitoring, and GP003 for requirements

regarding SO2 and NOx monitoring. The SO2 and NOx monitors shall be capable

of producing emission rates in units of lb/mmBtu on a one-hour average, a

three-hour average and on a 30-day rolling average.

40 CFR Section 75.10

Minn. R. 7017.1020

Operate and maintain the continuous opacity monitor as a partial indicator of

compliance with the particulate matter limit.

40 CFR Part 64

PERFORMANCE TESTING hdr

Performance Test: due before end of each 60 months starting 09/16/1997 to

determine compliance with the Title I condition particulate matter emission limit.

The tests shall be conducted at an interval not to exceed 60 months between test

dates.

Title I Condition: monitoring for the particulate matter

emission limit set under 40 CFR 52.21; Minn. R.

7017.2020, subp. 1, and 40 CFR Part 64

Boiler Alternative Operating Conditions for Performance Testing:

Alternative Operating Conditions during testing are defined as 90% to 100% of the

boiler's maximum normal (continuous) operating load or the maximum permitted

operating rate, whichever is lower. The basis for this number must be included in

the test plan. If testing is conducted at the alternative operating condition

established, an operating limit will not be established as a result of performance

testing.

In no case will the new operating rate limit be higher than allowed by an existing

permit condition.

Minn. R. 7017.2025, Subp. 2(A) and 3(B)

Boiler Operating Conditions Not Meeting the Alternative Operating Conditions

During Performance Testing:

If performance testing is not conducted at or above the established alternative

operating condition, then the boiler operating rate will be limited on an 8-hour block

average based on the following:

(1) If the results of the performance test are greater than 80% of any applicable

emission limit for which compliance is demonstrated, then boiler operation will be

limited to the tested operating rate.

(2) If results are less than or equal to 80% of all applicable emission limits for which

compliance is demonstrated, boiler operation will be limited to 110% of the tested

operating rate.

In no case will the new operating rate limit be higher than allowed by an existing

permit condition.

Minn. R. 7017.2025, Subp. 3(B)

STET (Short Term Emergency and Testing) Operating hours limit:

The boiler may operate up to 40 hours per year to demonstrate the Uniform Rating

of Generating Equipment (URGE) capacity and to meet emergency energy supply

needs. Maintain documentation of all STET operation to demonstrate compliance

with this limit. The boiler must meet emission limits during STET operation.

Minn. R. 7007.0800, Subp. 2.

STET Operation Definition that applies to Boilers that Meet or do Not Meet the

Alternative Operating Condition for Performance Testing:

If performance test results demonstrate compliance at 80% or less of any

applicable emission limits for any tested pollutant, STET operation is defined as

operation beyond 110% of the average operating rate achieved during that

performance test.

If performance test results demonstrate compliance at greater than 80% any

applicable emission limit for any tested pollutant, STET operation is defined as

operation beyond 100% of the average operating rate achieved during that

performance test.

In no case will STET operation be higher than allowed by an existing permit

condition.

Minn. R. 7007.0800, Subp. 2.
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-13

The results of a performance test are not final until issuance of a review letter by

MPCA, unless specified otherwise by Minn. R. 7017.2001 - 7017.2060.

Minn. R. 7017.2020, Subp. 4.

Performance Test: due 180 days after Permit Issuance to measure PM10

emissions.

This test shall be conducted with the rotating opposed fired air and selective

non-catalytic reduction control systems in operation.

Testing is required to confirm conclusion of the permitting assessment conducted in

June 2008 for the addition of rotating opposed fired air and selective non-catalytic

reduction. The Permittee shall submit a report updating the June 2008 permitting

assessment incorporating results of this testing no later than 90 days following

completion of testing.

Title I condition: 40 CFR Section 52.21; Test to confirm

the modification is not subject to PSD; Minn. R.

7017.2020, subp. 1
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-14

Subject Item: EU 002 Power Boiler 2 

Associated Items: CE 002 Fabric Filter - High Temperature, i.e., T>250 Degrees F

GP 004 Boilers 1-4 Sulfur Dioxide Limits

MR 002 Blr 1, 2, and 3 SO2

MR 003 Blr 1, 2, and 3 CO2

MR 004 Blr 1 and 2 NOx

MR 021 Blr 2 Opacity

MR 032 Blr 2 SO2

MR 033 Blr 2 NOx

MR 034 Blr 2 CO2

MR 035 Blr 2 Air Flow

SV 001 

SV 003 

What to do Why to do it

EMISSION LIMITS hdr

Total Particulate Matter: less than or equal to 0.1 lbs/million BTU heat input Title I condition: 40 CFR Section 52.21(k) (ambient air

impacts analysis); also meets the requirements of

Minn. R. 7011.0510, subp. 1

Opacity: less than or equal to 20 percent opacity using 6-minute Average except for

one six-minute period per hour of not more than 60 percent opacity.

Minn. R. 7011.0510, subp. 2

See GP004 for sulfur dioxide limits. hdr

Comply with the applicable Acid Rain emissions limitation for sulfur dioxide. 40 CFR Section 72.9(c)(1)(ii), 40 CFR Section

72.9(g)(4)

NOx Averaging Plan

Maintain an annual average NOx emission rate of 0.46 lbs/MMBtu and limit the

annual heat input to less than or equal to 3,500,000 mmBtu per year.

 OR

Maintain a Btu-weighted annual average emission rate in lbs/mmBtu, averaged

over the units specified in the NOx averaging plan, that is less than or equal to the

Btu-weighted annual average emission rate averaged over the same units had they

each been operated during the same period of time in compliance with the

applicable emission limitations in 40 CFR Sections 76.5, 76.6, or 76.7. Units

covered in the plan are:

Plant Boiler ID#

Clay Boswell 1, 2, 3, 4

Syl Laskin 1, 2

Taconite Harbor 1, 2, 3

40 CFR Section 76.11

Minn. R. 7011.0553

OPERATIONAL LIMITS AND REQUIREMENTS hdr

Fuel use: limited to sub-bituminous coal, boiler cleaning agents, distillate oil, oily

coal, used oil, oily paper-based floor dry, pipeline quality natural gas, and propane.

Minn. R. 7007.0800, subp. 2

Boiler cleaning agents limited to: EDTA type and Ammonium Bromate, are

generated on-site, 5% of total mass input, oxygen limited to 3% or greater, agents

may only be burned while the boiler is operating at 75 percent of rated capacity or

greater.

Minn. R. 7007.0800, subp. 2

Burn off-specification and on-specification used oil in accordance with Minn. R. ch.

7045, not to exceed 17.5% of rated heat input on an hourly basis (equal to 963

gallons/hr.).

Minn. R. 7007.0800, subp. 2
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-15

Vent all emissions to a fabric filter that meets the requirements of CE002 for

particulate matter control when burning coal. The fabric filter may be bypassed

during startup.

Bypassing of the fabric filter shall be for as short a time as is practicable while

avoiding damage to the fabric filter and it components, but shall not exceed 8 hours.

Title I Condition: control of particulate emissions.

CONTINUOUS MONITORING REQUIREMENTS hdr

The owner or operator shall measure opacity, and all SO2, NOx, and CO2

emissions from affected units in accordance with 40 CFR Section 75.10. See

GP002 for requirements regarding opacity monitoring, and GP003 for requirements

regarding SO2 and NOx monitoring. The SO2 and NOx monitors shall be capable

of producing emission rates in units of lb/mmBtu on a one-hour average, a

three-hour average and on a 30-day rolling average.

40 CFR Section 75.10

Minn. R. 7017.1020

Operate and maintain the continuous opacity monitor as a partial indicator of

compliance with the particulate matter limit.

40 CFR Part 64

PERFORMANCE TESTING hdr

Performance Test: due before end of each 60 months starting 09/16/1997 to

determine compliance with the Title I condition particulate matter emission limit.

The tests shall be conducted at an interval not to exceed 60 months between test

dates.

Title I Condition: monitoring for the particulate matter

emission limit set under 40 CFR 52.21; Minn. R.

7017.2020, subp. 1, and 40 CFR Part 64

Boiler Alternative Operating Conditions for Performance Testing:

Alternative Operating Conditions during testing are defined as 90% to 100% of the

boiler's maximum normal (continuous) operating load or the maximum permitted

operating rate, whichever is lower. The basis for this number must be included in

the test plan. If testing is conducted at the alternative operating condition

established, an operating limit will not be established as a result of performance

testing.

In no case will the new operating rate limit be higher than allowed by an existing

permit condition.

Minn. R. 7017.2025, Subp. 2(A) and 3(B)

Boiler Operating Conditions Not Meeting the Alternative Operating Conditions

During Performance Testing:

If performance testing is not conducted at or above the established alternative

operating condition, then the boiler operating rate will be limited on an 8-hour block

average based on the following:

(1) If the results of the performance test are greater than 80% of any applicable

emission limit for which compliance is demonstrated, then boiler operation will be

limited to the tested operating rate.

(2) If results are less than or equal to 80% of all applicable emission limits for which

compliance is demonstrated, boiler operation will be limited to 110% of the tested

operating rate.

In no case will the new operating rate limit be higher than allowed by an existing

permit condition.

Minn. R. 7017.2025, Subp. 3(B)

STET (Short Term Emergency and Testing) Operating hours limit:

The boiler may operate up to 40 hours per year to demonstrate the Uniform Rating

of Generating Equipment (URGE) capacity and to meet emergency energy supply

needs. Maintain documentation of all STET operation to demonstrate compliance

with this limit. The boiler must meet emission limits during STET operation.

Minn. R. 7007.0800, Subp. 2.

STET Operation Definition that applies to Boilers that Meet or do Not Meet the

Alternative Operating Condition for Performance Testing:

If performance test results demonstrate compliance at 80% or less of any

applicable emission limits for any tested pollutant, STET operation is defined as

operation beyond 110% of the average operating rate achieved during that

performance test.

If performance test results demonstrate compliance at greater than 80% any

applicable emission limit for any tested pollutant, STET operation is defined as

operation beyond 100% of the average operating rate achieved during that

performance test.

In no case will STET operation be higher than allowed by an existing permit

condition.

Minn. R. 7007.0800, Subp. 2.
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-16

The results of a performance test are not final until issuance of a review letter by

MPCA, unless specified otherwise by Minn. R. 7017.2001 - 7017.2060.

Minn. R. 7017.2020, Subp. 4.

Performance Test: due 180 days after Permit Issuance to measure PM10

emissions.

This test shall be conducted with the over-fire air and selective non-catalytic

reduction control systems in operation.

Testing is required to confirm conclusion of the permitting assessment conducted in

June 2008 for the addition of rotating opposed fired air and selective non-catalytic

reduction. The Permittee shall submit a report updating the June 2008 permitting

assessment incorporating results of this testing no later than 90 days following

completion of testing.

Title I condition: 40 CFR Section 52.21; Test to confirm

the modification is not subject to PSD; Minn. R.

7017.2020, subp. 1
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-17

Subject Item: EU 003 Power Boiler 3

Associated Items: CE 012 Wet Scrubber - High Efficiency

CE 019 Modified Furnace or Burner Design

CE 020 Catalytic Reduction

CE 021 Fabric Filter - High Temperature, i.e., T>250 Degrees F

CE 022 Wet Limestone Injection

GP 004 Boilers 1-4 Sulfur Dioxide Limits

MR 002 Blr 1, 2, and 3 SO2

MR 003 Blr 1, 2, and 3 CO2

MR 016 Blr 3 NOx

MR 024 Boiler 3 CO

MR 025 Blr 3 Mercury

MR 027 Boiler 3 Opacity

MR 036 Blr 3 SO2

MR 037 Blr 3 NOx

MR 038 Blr 3 CO2

MR 039 Blr 3 Air Flow

SV 003 

What to do Why to do it

EMISSION LIMITS hdr

Total Particulate Matter: less than or equal to 0.6 lbs/million Btu heat input . This

limit applies prior to modification of Boiler 3 and its pollution control stream.

Minn. R. 7011.0510, subp. 1

Total Particulate Matter: less than or equal to 0.014 lbs/million Btu heat input for

filterable PM. This limit applies upon return of Unit 3 to regular operation after

modification of the boiler and its pollution control equipment stream.

Minn. R. 7007.0800, subp. 2

Particulate Matter < 10 micron: less than or equal to 0.035 lbs/million Btu heat input

filterable plus organic and inorganic condensables. This limit applies upon return of

Unit 3 to regular operation after modification of the boiler and its pollution control

equipment stream.

Minn. R. 7007.0800, subp. 2

Opacity: less than or equal to 20 percent opacity using 6-minute Average except for

one six-minute period per hour of not more than 60 percent opacity.

Minn. R. 7011.0510, subp. 2

NOx Averaging Plan

Maintain an annual average NOx emission rate of 0.40 lbs/MMBtu and limit the

annual heat input to less than or equal to 19,000,000 mmBtu per year.

 OR

Maintain a Btu-weighted annual average emission rate in lbs/mmBtu, averaged

over the units specified in the NOx averaging plan, that is less than or equal to the

Btu-weighted annual average emission rate averaged over the same units had they

each been operated during the same period of time in compliance with the

applicable emission limitations in 40 CFR Sections 76.5, 76.6, or 76.7. Units

covered in the plan are:

Plant Boiler ID#

Clay Boswell 1, 2, 3, 4

Syl Laskin 1, 2

Taconite Harbor 1, 2, 3

40 CFR Section 76.8 Early election for Group 1, Phase

II boilers and 40 CFR Section 76.5(a)(1)

Minn. R. 7011.0553
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-18

Nitrogen Oxides: less than or equal to 0.07 lbs/million Btu heat input based on a

30-day rolling average. This limit does not apply during times of startup, shutdown

or malfunction.

This limit applies upon return of Unit 3 to regular operation after modification of the

boiler and its pollution control equipment stream.

Minn. R. 7007.0800, subp. 2

See GP004 for sulfur dioxide limits. hdr

Hydrogen fluoride: less than or equal to 0.0018 lbs/million Btu heat input . This limit

applies upon return of Unit 3 to regular operation after modification of the boiler and

its pollution control equipment stream.

Title I Condition: to avoid major modification

classification under 40 CFR Section 52.21 and Minn.

R. 7007.3000

Carbon Monoxide: less than or equal to 0.15 lbs/million Btu heat input on a 24-hour

rolling average. This limit does not apply during periods of startup, shutdown, or

malfunction. This limit applies upon return of Unit 3 to regular operation after

modification of the boiler and its pollution control equipment stream.

Title I Condition: 40 CFR Section 52.21 BACT limit

Lead: less than or equal to 0.00004 lbs/million Btu heat input . This limit applies

upon return of Unit 3 to regular operation after modification of the boiler and its

pollution control equipment stream.

Title I Condition: to avoid major modification

classification under 40 CFR Section 52.21 and Minn.

R. 7007.3000

OPERATING REQUIREMENTS hdr

Regular operation for Unit 3 is defined as operation at more than 200 net MW of

load for more than 7 days in a row after modification of the boiler and its pollution

control equipment stream.

Minn. R. 7007.0800, subp. 2

Fuel use: limited to sub-bituminous coal, boiler cleaning agents, distillate oil, oily

coal, used oil, wastewater treatment plant sludge, oily paper-based floor dry,

pipeline quality natural gas, propane, and oily materials (includes mixtures of earth

substrate (soil, rocks, sod, etc.) or man-made petroleum adsorption material and

various petroleum derived fuels (hydraulic, transformer (less than 50 ppm PCB),

crankcase or lubricating oils, diesel fuel, and crude oil)).

Note: the Permittee is prohibited from using oily materials or wastewater treatment

plant sludge as fuel until the Permittee satisfactorily completes the performance

testing requirements for these fuels under EU003.

Minn. R. 7007.0800, subp. 2

Boiler cleaning agents limited to: EDTA type and Ammonium Bromate, are

generated on-site, 5% of total mass input, oxygen limited to 3% or greater, agents

may only be burned while the boiler is operating at 75 percent of rated capacity or

greater.

Minn. R. 7007.0800, subp. 2

Burn off-specification and on-specification used oil in accordance with Minn. R. ch.

7045, and not to exceed 2,456 gallons per hour.

Minn. R. 7007.0800, subp. 2

Vent all emissions to a scrubber for particulate control until the boiler and its

pollution control equipment stream are modified. After return to regular operation

vent all emissions to a selective catalytic reduction system, a fabric filter, and sulfur

dioxide scrubber.

Minn. R. 7007.0800, subp. 2

CONTINUOUS MONITORING hdr

Measure all Opacity, SO2, NOx, and CO2 emissions from affected units in

accordance with 40 CFR Section 75.10. See GP002 for requirements regarding

opacity monitoring, and GP003 for requirements regarding SO2 and NOx

monitoring. The SO2 and NOx monitors shall be capable of producing emission

rates in units of lb/mmBtu on a one-hour average, a three-hour average and on a

30-day rolling average.

The opacity monitor shall be installed upon return of Unit 3 to regular operation as

defined in this permit, and shall be located after the fabric filter and prior to the flue

gas desulfurization unit.

40 CFR Section 75.10

Minn. R. 7017.1020

40 CFR Part 64

Install and operate a continuous emission monitor to measure all CO emissions.

The monitor shall be capable of producing emission rates in units of lb/mmBtu on a

24 hour rolling average. See GP003 for requirements regarding CO monitoring.

The carbon monoxide monitor shall be installed upon return of Unit 3 to regular

operation as defined in this permit.

Title I Condition: monitoring for BACT limit and Minn.

R. 7007.0800, subp. 4

Operate and maintain the continuous opacity monitor as a partial indicator of

compliance with the particulate matter limit after return to regular operation

following modification of the boiler and its pollution control equipment stream.

40 CFR Part 64

Mercury Emissions Monitoring: Use a Hg CEMS to measure Hg emissions from

EU 003 by July 1, 2007. Additional Hg monitoring requirements are located under

subject item MR 025.

Minn. Statute 216B.681
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-19

Establish Baseline Mercury Emission Rate: Use mercury monitors to establish the

baseline mercury emission rate for EU 003.

This is a state only requirement and is not enforceable by the EPA administrator

and citizens under the Clean Air Act.

Minn. Stat. 216B.681

PERFORMANCE TESTING hdr

Initial Performance Test: due 180 days after achieving maximum capacity for PM

and PM10 after modification of Boiler 3 and its pollution control equipment stream.

Minn. R. 7017.2020, subp. 1

40 CFR Part 64

Initial Performance Test: due 180 days after achieving maximum capacity for

hydrogen fluoride after modification of Boiler 3 and its pollution control equipment

stream.

Title I Condition: to avoid major modification

classification under 40 CFR Section 52.21 and Minn.

R. 7007.3000

Initial Performance Test: due 180 days after achieving maximum capacity for Lead

after modification of Boiler 3 and its pollution control equipment stream.

Title I Condition: to avoid major modification

classification under 40 CFR Section 52.21 and Minn.

R. 7007.3000

Boiler Alternative Operating Conditions for Performance Testing:

Alternative Operating Conditions during testing are defined as 90% to 100% of the

boiler's maximum normal (continuous) operating load or the maximum permitted

operating rate, whichever is lower. The basis for this number must be included in

the test plan. If testing is conducted at the alternative operating condition

established, an operating limit will not be established as a result of performance

testing.

In no case will the new operating rate limit be higher than allowed by an existing

permit condition.

Minn. R. 7017.2025, Subp. 2(A) and 3(B)

Boiler Operating Conditions Not Meeting the Alternative Operating Conditions

During Performance Testing:

If performance testing is not conducted at or above the established alternative

operating condition, then the boiler operating rate will be limited on an 8-hour block

average based on the following:

(1) If the results of the performance test are greater than 80% of any applicable

emission limit for which compliance is demonstrated, then boiler operation will be

limited to the tested operating rate.

(2) If results are less than or equal to 80% of all applicable emission limits for which

compliance is demonstrated, boiler operation will be limited to 110% of the tested

operating rate.

In no case will the new operating rate limit be higher than allowed by an existing

permit condition.

Minn. R. 7017.2025, Subp. 3(B)

STET (Short Term Emergency and Testing) Operating hours limit:

The boiler may operate up to 40 hours per year to demonstrate the Uniform Rating

of Generating Equipment (URGE) capacity and to meet emergency energy supply

needs. Maintain documentation of all STET operation to demonstrate compliance

with this limit. The boiler must meet emission limits during STET operation.

Minn. R. 7007.0800, Subp. 2.

STET Operation Definition that applies to Boilers that Meet or do Not Meet the

Alternative Operating Condition for Performance Testing:

If performance test results demonstrate compliance at 80% or less of any

applicable emission limits for any tested pollutant, STET operation is defined as

operation beyond 110% of the average operating rate achieved during that

performance test.

If performance test results demonstrate compliance at greater than 80% any

applicable emission limit for any tested pollutant, STET operation is defined as

operation beyond 100% of the average operating rate achieved during that

performance test.

In no case will STET operation be higher than allowed by an existing permit

condition.

Minn. R. 7007.0800, Subp. 2.

The results of a performance test are not final until issuance of a review letter by

MPCA, unless specified otherwise by Minn. R. 7017.2001 - 7017.2060.

Minn. R. 7017.2020, Subp. 4.
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-20

Performance Test: due 30 days after Performance Test Notification (written) of

intent to conduct a performance test while burning waste water sludge. The test

shall be for determining compliance with the particulate matter emission limit in

Minn. R. 7011.0510, subp. 1. The Permittee shall also concurrently measure CO

emissions. Except for the purpose of conducting this performance test, the

Permittee shall not use this material as a fuel until the Permittee receives

notification from the agency that compliance was demonstrated during the Waste

Water Sludge Performance Test.

Minn. R. 7017.2020, subp. 1.

Performance Test: due 30 days after Performance Test Notification (written) of

intent to conduct a performance test while burning oily materials. The test shall be

for determining compliance with the particulate matter emission limit in Minn. R.

7011.0510, subp. 1. The Permittee shall also concurrently measure CO emissions.

Except for the purpose of conducting this performance test, the Permittee shall not

use this material as a fuel until the Permittee receives notification from the agency

that compliance was demonstrated during the Oily Materials Performance Test.

Minn. R. 7017.2020, subp. 1.

Opacity monitoring alternative - monitor the following operating parameters for CE

003: 1) prequench slurry flow; 2) prequench slurry pressure; 3) high pressure slurry

flow; 4) high pressure slurry pressure. (See requirements under CE 003).

Minn. R. 7007.0800, subp. 4

Compliance Assurance Monitoring Plan: Sixty days after return to regular

operation as defined in this permit, submit a plan for developing opacity magnitude

and duration levels to be used as triggers for fabric filter investigation. This plan

will also identify specific investigation actions to be taken by plant personnel when

the triggers are reached.

Submit trigger levels and related specific actions with 180 days after return to

regular operation in the form of a major amendment application. Implement plan

upon submittal. Terms identified in the permit application will be incorporated as

permit conditions.

Minn. R. 7007.0800 , subp. 4 and 40 CFR Part 64

SUBMITTALS AND REPORTING hdr

See Table B. hdr
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-21

Subject Item: EU 004 Power Boiler 4

Associated Items: CE 004 Venturi Scrubber

CE 005 Electrostatic Precipitator - High Efficiency

CE 006 Spray Tower

CE 011 Fly Ash Injection

GP 004 Boilers 1-4 Sulfur Dioxide Limits

MR 006 Blr 4 CO2

MR 007 Blr 4 SO2

MR 008 Blr 4 NOx

MR 026 Blr 4 Mercury

MR 040 Blr 4 Opacity

MR 041 Blr 4 Air Flow

SV 004 

What to do Why to do it

EMISSION LIMITS hdr

Total Particulate Matter: less than or equal to 0.1 lbs/million BTU heat input Title I Condition: 40 CFR Section 52.21(j) PSD BACT

limit and ambient impacts analysis; 40 CFR Section

60.42(a)(1)

Opacity: less than or equal to 20 percent opacity based on a six minute average,

except for one six-minute average per hour not to exceed 27%

40 CFR Section 60.42(a)(2)

Minn. R. 7011.0555

See GP004 for sulfur dioxide limits. hdr

Comply with the applicable Acid Rain emissions limitation for sulfur dioxide. Takes

effect for years beginning January 1, 2000.

40 CFR Section 72.9(c)(1)(ii), 40 CFR Section

72.9(g)(4)

Nitrogen Oxides: less than or equal to 0.7 lbs/million Btu heat input using 3-hour

Average for solid fossil fuels, less than 0.3 lb/mmBtu from liquid fossil fuels, and

less then 0.2 lb/mmBtu for gaseous fossil fuels. When fossil fuels are burned

simultaneously in any combination, the applicable standard shall be determined by

proration using the following formula: PS = [0.2x + 0.3y + 0.7z]/(x+y+z) where PS is

the prorated NOx standard, x is the % heat input from gaseous fossil fuels, y is the

% heat input from liquid fossil fuels, and z is the % heat input from solid fossil fuels.

Title I Condition: 40 CFR Section 52.21(j) PSD BACT

limit and ambient impacts analysis; 40 CFR Section

60.44

NOx Averaging Plan

Maintain an annual average NOx emission rate of 0.40 lbs/MMBtu and limit the

annual heat input to less than or equal to 33,000,000 mmBtu per year.

 OR

Maintain a Btu-weighted annual average emission rate in lbs/mmBtu, averaged

over the units specified in the NOx averaging plan, that is less than or equal to the

Btu-weighted annual average emission rate averaged over the same units had they

each been operated during the same period of time in compliance with the

applicable emission limitations in 40 CFR Sections 76.5, 76.6, or 76.7. Units

covered in the plan are:

Plant Boiler ID#

Clay Boswell 1, 2, 3, 4

Syl Laskin 1, 2

Taconite Harbor 1, 2, 3

40 CFR Section 76.11

Minn. R. 7011.0553

OPERATING REQUIREMENTS hdr

Fuel use: limited to sub-bituminous coal, boiler cleaning agents, distillate oil, oily

coal, oily paper-based floor dry, used oil, pipeline quality natural gas, and propane.

Minn. R. 7007.0800, subp. 2

Boiler cleaning agents limited to: EDTA type and Ammonium Bromate, are

generated on-site, 5% of total mass input, oxygen limited to 3% or greater, agents

may only be burned while the boiler is operating at 75 percent of rated capacity or

greater.

Minn. R. 7007.0800, subp. 2
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-22

Burn off-specification and on-specification used oil in accordance with Minn. R. ch.

7045, not to exceed 3824 gallons/hour (approximately 10 percent of rated capacity

of 5,109 mmBtu/hour) on an hourly basis.

Minn. R. 7007.0800, subp. 2

Maintain SV 004 exit flue gas temperature at a minimum of 135 degrees F. Minn. R. 7009

Vent all emissions to a venturi scrubber, electrostatic precipitator and spray tower. Title I Condition: control of particulate matter and sulfur

dioxide

PERFORMANCE TESTING hdr

Performance Test: due before end of each 60 months starting 09/27/1997 to

determine compliance with the Title I condition particulate matter emission limit.

The tests shall be conducted at an interval not to exceed 60 months between test

dates.

Title I Condition: monitoring for the particulate

emission limit set under 40 CFR Section 52.21; Minn.

R. 7017.2020, subp. 1

Boiler Alternative Operating Conditions for Performance Testing:

Alternative Operating Conditions during testing are defined as 90% to 100% of the

boiler's maximum normal (continuous) operating load or the maximum permitted

operating rate, whichever is lower. The basis for this number must be included in

the test plan. If testing is conducted at the alternative operating condition

established, an operating limit will not be established as a result of performance

testing.

In no case will the new operating rate limit be higher than allowed by an existing

permit condition.

Minn. R. 7017.2025, Subp. 2(A) and 3(B)

Boiler Operating Conditions Not Meeting the Alternative Operating Conditions

During Performance Testing:

If performance testing is not conducted at or above the established alternative

operating condition, then the boiler operating rate will be limited on an 8-hour block

average based on the following:

(1) If the results of the performance test are greater than 80% of any applicable

emission limit for which compliance is demonstrated, then boiler operation will be

limited to the tested operating rate.

(2) If results are less than or equal to 80% of all applicable emission limits for which

compliance is demonstrated, boiler operation will be limited to 110% of the tested

operating rate.

In no case will the new operating rate limit be higher than allowed by an existing

permit condition.

Minn. R. 7017.2025, Subp. 3(B)

STET (Short Term Emergency and Testing) Operating hours limit:

The boiler may operate up to 40 hours per year to demonstrate the Uniform Rating

of Generating Equipment (URGE) capacity and to meet emergency energy supply

needs. Maintain documentation of all STET operation to demonstrate compliance

with this limit. The boiler must meet emission limits during STET operation.

Minn. R. 7007.0800, Subp. 2.

STET Operation Definition that applies to Boilers that Meet or do Not Meet the

Alternative Operating Condition for Performance Testing:

If performance test results demonstrate compliance at 80% or less of any

applicable emission limits for any tested pollutant, STET operation is defined as

operation beyond 110% of the average operating rate achieved during that

performance test.

If performance test results demonstrate compliance at greater than 80% any

applicable emission limit for any tested pollutant, STET operation is defined as

operation beyond 100% of the average operating rate achieved during that

performance test.

In no case will STET operation be higher than allowed by an existing permit

condition.

Minn. R. 7007.0800, Subp. 2.

The results of a performance test are not final until issuance of a review letter by

MPCA, unless specified otherwise by Minn. R. 7017.2001 - 7017.2060.

Minn. R. 7017.2020, Subp. 4.

CONTINUOUS MONITORING REQUIREMENTS hdr
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-23

Measure all Opacity, SO2, NOx, and CO2 emissions from affected units in

accordance with 40 CFR Section 75.10. See GP002 for requirements regarding

opacity monitoring, and GP003 for requirements regarding SO2 and NOx

monitoring. The SO2 and NOx monitors shall be capable of producing emission

rates in units of lb/mmBtu on a one-hour average, a three hour average and on a

30-day rolling average.

Using the 30-day averages for SO2, calculate and submit the annual SO2 emission

rate along with the annual compliance certification.

40 CFR Section 75.10 and Minn. R. 7017

Operate and maintain the continuous opacity monitor as a partial indicator of

compliance with the particulate matter limit.

40 CFR Part 64

Measure stack gas exit temperature. Minn. R. 7009

Mercury Emissions Monitoring: Use a Hg CEMS to measure Hg emissions from

EU 004 by July 1, 2007. Additional Hg monitoring requirements are located under

subject item MR 026.

Minn. Stat. 216B.681

Establish Baseline Mercury Emission Rate: Use mercury monitors to establish the

baseline mercury emission rate for EU 004.

This is a state only requirement and is not enforceable by the EPA administrator

and citizens under the Clean Air Act.

Minn. Stat. 216B.681

REPORTING hdr

Submit the calculations and annual average emission rate of sulfur dioxide along

with the annual compliance certification.

Minn. R. 7021.0050
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-24

Subject Item: EU 007 Emergency Generator 1

Associated Items: SV 007 

What to do Why to do it

Opacity: less than or equal to 20 percent opacity once operating temperatures have

been attained.

Minn. R. 7011.2300, subp. 1

Sulfur Dioxide: less than or equal to 0.5 lbs/million Btu heat input Minn. R. 7011.2300, subp. 2

Fuel type: liquid propane only Minn. R. 7005.0100, subp. 35a
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-25

Subject Item: EU 009 Emergency Generator 3

Associated Items: SV 009 Diesel Emergency Generator 3

What to do Why to do it

Opacity: less than or equal to 20 percent opacity once operating temperatures have

been attained.

Minn. R. 7011.2300, subp. 1

Sulfur Dioxide: less than or equal to 0.5 lbs/million Btu heat input Minn. R. 7011.2300, subp. 2

Fuel type: Diesel fuel oil or distillate fuel oil only Minn. R. 7005.0100, subp. 35a

Fuel Supplier Certification: The Permittee shall obtain and maintain a fuel supplier

certification for each shipment of fuel oil, certifying that the sulfur content does not

exceed 0.5% by weight.

Minn. R. 7007.0800, subps. 4 & 5
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-26

Subject Item: EU 010 Emergency Generator 4

Associated Items: SV 010 

What to do Why to do it

Opacity: less than or equal to 20 percent opacity once operating temperatures have

been attained.

Minn. R. 7011.2300, subp. 1

Sulfur Dioxide: less than or equal to 0.5 lbs/million Btu heat input Minn. R. 7011.2300, subp. 2

Fuel type: Diesel fuel oil or distillate fuel oil only Minn. R. 7005.0100, subp. 35a

Fuel Supplier Certification: The Permittee shall obtain and maintain a fuel supplier

certification for each shipment of fuel oil, certifying that the sulfur content does not

exceed 0.5% by weight.

Minn. R. 7007.0800, subps. 4 & 5
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-27

Subject Item: EU 011 Coal Handling-Crusher Building

Associated Items: CE 007 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 011 

What to do Why to do it

Total Particulate Matter: less than or equal to 0.3 grains/dry standard cubic foot of

exhaust gas unless required to further reduce emissions to comply with the less

stringent limit of either Minn. R. 7011.0730 or Minn. R. 7011.0735.

Minn. R. 7011.0715, subp. 1(A)

Opacity: less than or equal to 20 percent opacity Minn. R. 7011.0715, subp. 1(B)

Operate fabric filter when emissions from the equipment are vented to the

atmosphere that meets the requirements of GP005.

Minn. Stat. Section 116.07, subd. 4(a);

Minn. R. 7007.0800, subp. 2
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-28

Subject Item: EU 012 Coal Handling-Crusher & Sampler House

Associated Items: CE 008 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 012 

What to do Why to do it

Total Particulate Matter: less than or equal to 0.3 grains/dry standard cubic foot of

exhaust gas unless required to further reduce emissions to comply with the less

stringent limit of either Minn. R. 7011.0730 or Minn. R. 7011.0735.

Minn. R. 7011.0715, subp. 1(A)

Opacity: less than or equal to 20 percent opacity Minn. R. 7011.0715, subp. 1(B)

Operate fabric filter when emissions from the equipment are vented to the

atmosphere that meets the requirements of GP005.

Minn. Stat. Section 116.07, subd. 4(a);

Minn. R. 7007.0800, subp. 2
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-29

Subject Item: EU 013 Fly Ash - #1&2 Storage Silo

Associated Items: CE 009 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 013 

What to do Why to do it

Total Particulate Matter: less than or equal to 0.3 grains/dry standard cubic foot of

exhaust gas unless required to further reduce emissions to comply with the less

stringent limit of either Minn. R. 7011.0730 or Minn. R. 7011.0735.

Minn. R. 7011.0715, subp. 1(A)

Opacity: less than or equal to 20 percent opacity Minn. R. 7011.0715, subp. 1(B)

Operate fabric filter when emissions from the equipment are vented to the

atmosphere that meets the requirements of GP005.

Minn. Stat. Section 116.07, subd. 4(a);

Minn. R. 7007.0800, subp. 2
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-30

Subject Item: EU 014 Fly Ash - #1&2 Ash Hoppers

Associated Items: CE 010 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 014 

What to do Why to do it

Total Particulate Matter: less than or equal to 0.3 grains/dry standard cubic foot of

exhaust gas unless required to further reduce emissions to comply with the less

stringent limit of either Minn. R. 7011.0730 or Minn. R. 7011.0735.

Minn. R. 7011.0715, subp. 1(A)

Opacity: less than or equal to 20 percent opacity Minn. R. 7011.0715, subp. 1(B)

Operate fabric filter when emissions from the equipment are vented to the

atmosphere that meets the requirements of GP005.

Minn. Stat. Section 116.07, subd. 4(a);

Minn. R. 7007.0800, subp. 2
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-31

Subject Item: EU 015 Hg Additive Handling and Storage

Associated Items: CE 013 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 015 Additive Handling and Storage

What to do Why to do it

EMISSION LIMITS hdr

Total Particulate Matter: less than or equal to 0.01 grains/dry standard cubic foot

unless required to further reduce emissions to comply with the less stringent of

either Minn. R. 7011.0730 or Minn. R. 7011.0735.

Title I Condition: to avoid major modification

classification under 40 CFR Section 52.21 and Minn.

R. 7007.3000, also meets the requirements of Minn. R.

7011.0715 subp. 1(A)

Opacity: less than or equal to 20 percent Minn. R. 7011.0715, subp. 1(B)

OPERATING CONDITIONS hdr

Vent all emissions to a fabric filter that meets the requirements of GP005. Title I Condition: to avoid major source classification

under 40 CFR Section 52.21 and Minn. R. 7007.3000
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-32

Subject Item: EU 017 Fly Ash Storage - Bin Vent

Associated Items: CE 015 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 017 Fly Ash Storage-Bin Vent

What to do Why to do it

EMISSION LIMITS hdr

Total Particulate Matter: less than or equal to 0.005 grains/dry standard cubic foot

unless required to further reduce emissions to comply with the less stringent of

either Minn. R. 7011.0730 or Minn. R. 7011.0735.

Title I Condition: to limit potential emission increases

to less than significant under 40 CFR 52.21 and Minn.

R. 7007.3000, also meets the requirements of Minn. R.

7011.0715, subp. 1(A)

Opacity: less than or equal to 20 percent Minn. R. 7011.0715, subp. 1(B)

OPERATING CONDITIONS hdr

Vent all emissions to a fabric filter that meets the requirements of GP005. Title I Condition: to avoid major source classification

under 40 CFR Section 52.21 and Minn. R. 7007.3000
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-33

Subject Item: EU 018 Fly Ash Loadout

Associated Items: SV 018 Fly Ash Loadout via general vent

What to do Why to do it

EMISSION LIMITS hdr

Total Particulate Matter: less than or equal to 0.30 grains/dry standard cubic foot

unless required to further reduce emissions to comply with the less stringent limit of

either Minn. R. 7011.0730 or Minn. R. 7011.0735.

Minn. R. 7011.0715, subp. 1(A)

Opacity: less than or equal to 20 percent Minn. R. 7011.0715, subp. 1(B)

OPERATING REQUIREMENTS hdr

Add moisture to the flyash prior to loadout. Operation of the unit without moisture

addition shall be a reportable deviation.

Minn. R. 7007.0800, subp. 2
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-34

Subject Item: EU 019 Limestone Storage - Bin Vent

Associated Items: CE 016 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 019 Limestone Storage - Bin Vent

What to do Why to do it

EMISSION LIMITS hdr

Total Particulate Matter: less than or equal to 0.005 grains/dry standard cubic foot

unless required to further reduce emissions to comply with the less stringent of

either Minn. R. 7011.0730 or Minn. R. 7011.0735.

Title I Condition: to limit potential emission increases

to less than significant under 40 CFR 52.21 and Minn.

R. 7007.3000, also meets the requirements of Minn. R.

7011.0715, subp. 1(A)

Opacity: less than or equal to 20 percent Minn. R. 7011.0715, subp. 1(B)

OPERATING CONDITIONS hdr

Vent all emissions to a fabric filter that meets the requirements of GP005. Title I Condition: to avoid major source classification

under 40 CFR Section 52.21 and Minn. R. 7007.3000
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-35

Subject Item: EU 020 Limestone Day Bin 1

Associated Items: CE 017 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 020 Limestone Day Bin 1 - Bin Vent

What to do Why to do it

EMISSION LIMITS hdr

Total Particulate Matter: less than or equal to 0.005 grains/dry standard cubic foot

unless required to further reduce emissions to comply with the less stringent limit of

either Minn. R. 7011.0730 or Minn. R. 7011.0735.

Title I Condition: to limit potential emissions increases

to less than significant under 40 CFR 52.21 and Minn.

R. 7007.3000, also meets Minn. R. 7011.0715, subp.

1(A)

Opacity: less than or equal to 20 percent Minn. R. 7011.0715, subp. 1(B)

OPERATING REQUIREMENTS hdr

Vent all emissions to a fabric filter that meets the requirements of GP005. Title I Condition: to avoid major source classification

under 40 CFR Section 52.21 and Minn. R. 7007.3000
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-36

Subject Item: EU 021 Limestone Day Bin 2

Associated Items: CE 018 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 021 Limestone Day Bin 2 - Bin Vent

What to do Why to do it

EMISSION LIMITS hdr

Total Particulate Matter: less than or equal to 0.005 grains/dry standard cubic foot

unless required to further reduce emissions to comply with the less stringent limit of

either Minn. R. 7011.0730 or Minn. R. 7011.0735.

Title I Condition: to limit potential emission increases

to less than significant under 40 CFR 52.21 and Minn.

R. 7007.3000 , also meets Minn. R. 7011.0715, subp.

1(A)

Opacity: less than or equal to 20 percent Minn. R. 7011.0715, subp. 1(B)

OPERATING REQUIREMENTS hdr

Vent all emissions to a fabric filter that meets the requirements of GP005. Title I Condition: to avoid major source classification

under 40 CFR Section 52.21 and Minn. R. 7007.3000
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-37

Subject Item: EU 023 Emergency Gen. Unit 3 - 300Kw - CI

Associated Items: SV 022 Emergency Generator - Unit 3

What to do Why to do it

EMISSION LIMITS hdr

Opacity: less than or equal to 20 percent once operating temperatures have been

attained.

Minn. R. 7011.2300, subp. 1

Opacity: less than or equal to 20 percent during accelartion mode; 15 percent

during lugging mode; and 50 percent during the peaks in either the acceleration or

lugging modes.

40 CFR Section 60.4205(b)

Carbon Monoxide: less than or equal to 3.0 grams per kilowatt-hour. Title I Condition: 40 CFR Section 52.21(j), BACT

emission limit, also meets the requirements of 40 CFR

Section 60.4202.

Non-methane Hydrocarbons plus Nitrogen Oxides:

Less than or equal to 4.0 grams per kilowatt-hour

40 CFR Section 60.4205(b)

Total Particulate Matter: less than or equal to 0.20 grams per kilowatt-hour. 40 CFR Section 60.4205(b)

Sulfur Dioxide: less than or equal to 0.5 lbs/million Btu heat input . Combustion of

fuel with a sulfur content of 0.5 percent by weight or less meets this requirement.

Minn. R. 7011.2300, subp. 2

OPERATING REQUIREMENTS hdr

Beginning October 1, 2007, use diesel fuel that meets the requirements of 40 CFR

Section 80.510(a):

(1) Sulfur content. 500 parts per million (ppm) maximum.

(2) Cetane index or aromatic content, as follows:

(i) A minimum cetane index of 40; or

(ii) A maximum aromatic content of 35 volume percent.

40 CFR Section 60.4207(a)

Beginning October 1, 2010, use diesel fuel that meets the requirements of 40 CFR

Section 80.510(b):

(1) Sulfur content. 15 ppm maximum for Non-Road diesel fuel.

(2) Cetane index or aromatic content, as follows:

(i) A minimum cetane index of 40; or

(ii) A maximum aromatic content of 35 volume percent.

40 CFR Section 60.4207(b)

Owners and operators of pre-2011 model year stationary CI ICE subject to this

subpart may petition the Administrator for approval to use remaining non-compliant

fuel that does not meet the fuel requirements of paragraphs (a) and (b) of this

section beyond the dates required for the purpose of using up existing fuel

inventories. If approved, the petition will be valid for a period of up to 6 months. If

additional time is needed, the owner or operator is required to submit a new petition

to the Administrator.

40 CFR Section 60.4207(c)

Operate and maintain the engine according to the manufacturer's written

instructions or procedures developed by the owner or operator that are approved by

the engine manufacturer. Only change those settings that are permitted by the

manufacturer. The permittee shall also meet the requirements of 40 CFR parts 89,

94, and 1068 as they apply to you.

40 CFR Section 60.4211(a)

Meet the definition of "Emergency stationary internal combustion engine" - any

stationary internal combustion engine whose operation is limited to emergency

situations and required testing and maintenance. Examples include stationary ICE

used to produce power for critical networks or equipment (including power supplied

to portions of a facility) when electric power from the local utility (or the normal

power source, if the facility runs on its own power production) is interrupted, or

stationary ICE used to pump water in the case of fire or flood, etc. Stationary CI

ICE used to supply power to an electric grid or that supply power as part of a

financial arrangement with another entity are not considered to be emergency

engines.

40 CFR Section 60.4219
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-38

Operate the emergency engine for the purpose of maintenance checks and

readiness testing provided that the tests are recommended by Federal, State or

local government, the manufacturer, the vendor; or the insurance company

associated with the engine. Maintenance checks and readiness testing for the

emergency engine is limited to 100 hours per year. Anyone may petition the

Administrator for approval of additional hours to be used for maintenance checks

and readiness testing. A petition is not required if the owner or operator maintains

records indicating that the Federal State, or local standards require maintenance

and testing of emergency ICE beyond 100 hours per year.

There is no time limit of the use of emergency stationary ICE in emergency

situations. Any operation other than emergency operation, maintenance and

testing, as permitted in Section 60.4211, is prohibited.

40 CFR Section 60.4211(e)

After December 31, 2008, the permittee may not install a stationary CI ICE that

does not meet the applicable requirements for 2007 model year engines.

40 CFR Section 60.4208(a)

MONITORING hdr

Install a non-resettable hour meter prior to startup of the engine. 40 CFR Section 60.4209(a)

PERFORMANCE TESTING hdr

If the permittee conduct performance tests, the tests must be completed in

accordance with 40 CFR Section 60.4212(a) through 40 CFR Section 60.4212(d).

40 CFR Section 60.4212

Performance Test: due 180 days after achieving maximum capacity for CO

emissions.

Title I Condition: monitoring for CO BACT limit

COMPLIANCE DEMONSTRATION hdr

Operate and maintain the unit in accordance with the standards as required by 40

CFR Section 60.4205, according to the manufacturer's written instructions, or

according to the procedures developed by the owner or operator that are approved

by the engine manufacturer, for the entire life of the engine. Settings for the unit

may not be changed unless permitted by the manufacturer.

40 CFR Section 60.4206 and 40 CFR Section

60.4211(a)

The permittee must demonstrate compliance by purchasing an engine certified to

conform with the emission standards listed in 40 CFR Section 52.05(b) for the

same model year and maximum engine power. The engine must be installed and

configured according to the manufacturer's specifications.

40 CFR Section 60.4211(c)

Recordkeeping - Hours of operation: The permittee shall maintain documentation

on-site that the unit is to be used for emergency (including training and testing)

purposes, only that qualifies under the limitation above of 100 hours per year for

checks and readiness testing. (40 CFR Section 60.4211(e)).

Minn. R. 7007.0800, subps. 4 and 5

Recordkeeping - Fuel Type: The permittee shall keep records of the type of fuel

burned in this unit when in operation.

Minn. R. 7007.0800, subp. 4 and 5

The permittee shall maintain records of the operation of the engine in emergency

service that is recorded through the non-resettable hour meter. The record must

include the time of operation and the reason the generator was in operation during

that time. This requirement is applicable when using a generator whose model

year is 2012 or later, if the emergency engine also does not meet the standards for

non-emergency engines for the 2012 model.

40 CFR Section 60.4214(b)

40 CFR Part 63, Subp. ZZZZ hdr

Initial Notification: Submit an initial notification to the administrator as required by

40 CFR Section 63.9 within 120 days of initial startup. The initial notification shall

include the following information:

(i) The name and address of the owner or operator;

(ii) The address (i.e., physical location) of the affected source;

(iii) An identification of the relevant standard, or other requirement, that is the basis

of the notification and the source's compliance date;

(iv) A brief description of the nature, size, design, and method of operation of the

source and an identification of the types of emission points within the affected

source subject to the relevant standard and types of hazardous air pollutants

emitted; and

(v) A statement of whether the affected source is a major source or an area source.

40 CFR Section 63.9(b)(2)
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-39

In addition, the notification shall contain a statement that the facilities stationary

RICE has no additional requirements and explain the basis of the exclusion of the

unit from the requirements of 40 CFR Part 63, Subp. ZZZZ (for example, that it

operates exclusively as an emergency/limited use stationary RICE or is less than

500 hp).

continued from above
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-40

Subject Item: CE 001 Fabric Filter - High Temperature, i.e., T>250 Degrees F

Associated Items: EU 001 Power Boiler 1 

What to do Why to do it

The Permittee shall operate and maintain the control equipment such that it

achieves an overall control efficiency for Total Particulate Matter: greater than or

equal to 99 percent collection efficiency

Title I Condition and Minn. R. 7007.0800, subp. 2 and

14

The Permittee shall operate and maintain the fabric filter in accordance with the

Operation and Maintenance (O & M) Plan. The Permittee shall keep copies of the

O & M Plan available onsite for use by staff and MPCA staff.

Minn. R. 7007.0800, subp. 14

Corrective Actions: The Permittee shall take corrective action as soon as possible if

any of the following occur:

- the recorded opacity is outside the permitted range; or

- the fabric filter or any of its components are found during the inspections to need

repair.

Corrective actions shall return the opacity to within the permitted range, and/or

include completion of necessary repairs identified during the inspection, as

applicable. Corrective actions include, but are not limited to, those outlined in the O

& M Plan for the fabric filter. The Permittee shall keep a record of the type and date

of any corrective action taken for each filter.

Minn. R. 7007.0800, subp. 4, 5, and 14

COMPLIANCE ASSURANCE MONITORING hdr

The owner or operator shall comply with the approved monitoring for opacity. The

owner or operator shall measure the opacity by means of a COM.

Parameter range indicating normal operation is opacity as a six-minute average

less than or equal to 20 percent opacity.

40 CFR Section 64.3(b) or (d)

40 CFR Section 64.6(c)(1)(i)

40 CFR Section 64.6)c)(1)(ii)

Minn. R. 7017.0200

The owner or operator shall conduct the monitoring required under this part upon

permit issuance.

40 CFR Section 64.7(a)

Minn. R. 7017.0200

The owner or operator shall maintain the monitoring instruments and recorders,

including but not limited to maintaining necessary parts for routine repairs of the

monitoring equipment.

40 CFR Section 64.7(b)

Minn. R. 7017.0200

Continuous Operation: Except for, as applicable, monitoring malfunctions,

associated repairs, and required quality assurance or control activities, the owner

or operator shall conduct all monitoring in continuous operation at all times the

pollutant-specific emissions unit is operating.

40 CFR Section 64.7(c)

Minn. R. 7017.0200

Response to excursions or exceedances: Upon detecting an excursion or

exceedance, the owner or operator shall restore operation of the pollutant-specific

emissions unit to its normal or usual manner of operation as expeditiously as

practicable in accordance with good air pollution control practices for minimizing

emissions.

40 CFR Section 64.7(d)(1)

Minn. R. 7017.0200

Documentation of need for improved monitoring: After approval of monitoring

under this part, if the owner or operator identifies a failure to achieve compliance

with an emission limitation or standard for which the approved monitoring did not

provide an indication of an excursion or exceedance while providing valid data, or

the results of compliance or performance testing document a need to modify the

existing indicator ranges or designated conditions, the owner or operator shall

promptly notify the permitting authority and, if necessary, submit a proposed

modification to the part 70 permit to address the necessary monitoring changes.

40 CFR Section 64.7(e)

Minn. R. 7017.0200

The owner or operator shall maintain records of monitoring data, monitor

performance data, corrective actions taken, any written quality improvement plan

required pursuant to 64.8 and any activities undertaken to implement a quality

improvement plan, and other supporting information required to be maintained.

The owner or operator may maintain records on alternative media, such as

microfilm, computer files, magnetic tape disks, or microfiche, provided that the use

of such alternative media allows for expeditious inspection and review, and does

not conflict with other applicable recordkeeping requirements.

40 CFR Section 64.9(b)

Minn. R. 7017.0200

The owner or operator shall report exceedances or excursions under Section 64.7

and Section 64.8 when the exceedance or excursion are greater than the limit and

averaging period with the Semiannual Deviations Report.

40 CFR Section 64.9(a)(2)(i)

Minn. R. 7017.0200
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-41

Subject Item: CE 002 Fabric Filter - High Temperature, i.e., T>250 Degrees F

Associated Items: EU 002 Power Boiler 2 

What to do Why to do it

The Permittee shall operate and maintain the control equipment such that it

achieves an overall control efficiency for Total Particulate Matter: greater than or

equal to 99 percent collection efficiency

Title I Condition and Minn. R. 7007.0800, subp. 2 and

14

The Permittee shall operate and maintain the fabric filter in accordance with the

Operation and Maintenance (O & M) Plan. The Permittee shall keep copies of the

O & M Plan available onsite for use by staff and MPCA staff.

Minn. R. 7007.0800, subp. 14

Corrective Actions: The Permittee shall take corrective action as soon as possible if

any of the following occur:

- the recorded opacity is outside the permitted operating range; or

- the fabric filter or any of its components are found during the inspections to need

repair.

Corrective actions shall return the opacity to within the permitted range, and/or

include completion of necessary repairs identified during the inspection, as

applicable. Corrective actions include, but are not limited to, those outlined in the O

& M Plan for the fabric filter. The Permittee shall keep a record of the type and date

of any corrective action taken for each filter.

Minn. R. 7007.0800, subp. 4, 5, and 14

COMPLIANCE ASSURANCE MONITORING hdr

The owner or operator shall comply with the approved monitoring for opacity. The

owner or operator shall measure the opacity by means of a COM.

Parameter range indicating normal operation is opacity as a six-minute average

less than or equal to 20 percent opacity.

40 CFR Section 64.3(b) or (d)

40 CFR Section 64.6(c)(1)(i)

40 CFR Section 64.6)c)(1)(ii)

Minn. R. 7017.0200

The owner or operator shall conduct the monitoring required under this part upon

permit issuance.

40 CFR Section 64.7(a)

Minn. R. 7017.0200

The owner or operator shall maintain the monitoring instruments and recorders,

including but not limited to maintaining necessary parts for routine repairs of the

monitoring equipment.

40 CFR Section 64.7(b)

Minn. R. 7017.0200

Continuous Operation: Except for, as applicable, monitoring malfunctions,

associated repairs, and required quality assurance or control activities, the owner

or operator shall conduct all monitoring in continuous operation at all times the

pollutant-specific emissions unit is operating.

40 CFR Section 64.7(c)

Minn. R. 7017.0200

Response to excursions or exceedances: Upon detecting an excursion or

exceedance, the owner or operator shall restore operation of the pollutant-specific

emissions unit to its normal or usual manner of operation as expeditiously as

practicable in accordance with good air pollution control practices for minimizing

emissions.

40 CFR Section 64.7(d)(1)

Minn. R. 7017.0200

Documentation of need for improved monitoring: After approval of monitoring

under this part, if the owner or operator identifies a failure to achieve compliance

with an emission limitation or standard for which the approved monitoring did not

provide an indication of an excursion or exceedance while providing valid data, or

the results of compliance or performance testing document a need to modify the

existing indicator ranges or designated conditions, the owner or operator shall

promptly notify the permitting authority and, if necessary, submit a proposed

modification to the part 70 permit to address the necessary monitoring changes.

40 CFR Section 64.7(e)

Minn. R. 7017.0200

The owner or operator shall maintain records of monitoring data, monitor

performance data, corrective actions taken, any written quality improvement plan

required pursuant to 64.8 and any activities undertaken to implement a quality

improvement plan, and other supporting information required to be maintained.

The owner or operator may maintain records on alternative media, such as

microfilm, computer files, magnetic tape disks, or microfiche, provided that the use

of such alternative media allows for expeditious inspection and review, and does

not conflict with other applicable recordkeeping requirements.

40 CFR Section 64.9(b)

Minn. R. 7017.0200

The owner or operator shall report exceedances or excursions under Section 64.7

and Section 64.8 when the exceedance or excursion are greater than the limit and

averaging period with the Semiannual Deviations Report.

40 CFR Section 64.9(a)(2)(i)

Minn. R. 7017.0200
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-42

Subject Item: CE 003 Alkaline Fly Ash Scrubbing

What to do Why to do it

Opacity monitoring alternative - monitor the following operating parameters for

CE003: 1)prequench slurry flow; 2)prequench slurry pressure; 3)high pressure

slurry flow; 4)high pressure slurry pressure.

These requirements apply until the modification of Boiler 3 and its pollution control

equipment stream.

Minn. R. 7007.0800, subp. 4

Operate CE003 wet scrubber in accordance with the following operating

parameters, in order to determine compliance with the opacity limit under Minn. R.

7011.0510, subp. 2: a. Prequench slurry flow >4592 gpm Prequench slurry

pressure >32 psig b. High pressure slurry flow >4536 gpm High pressure slurry

pressure >158 psig

Minn. R. 7007.0800, subp. 2

Record once each hour of operation of EU003 for CE003: 1)prequench slurry flow

rate; 2)prequench slurry pressure; 3)high pressure slurry flow rate; 4)high pressure

slurry pressure.

Minn. R. 7007.0800, subp. 5

COMPLIANCE ASSURANCE MONITORING hdr

The owner or operator shall conduct the monitoring required under this part upon

permit issuance.

40 CFR Section 64.7(a)

Minn. R. 7017.0200

The owner or operator shall maintain the monitoring instruments and recorders,

including but not limited to maintaining necessary parts for routine repairs of the

monitoring equipment.

40 CFR Section 64.7(b)

Minn. R. 7017.0200

Continuous Operation: Except for, as applicable, monitoring malfunctions,

associated repairs, and required quality assurance or control activities, the owner

or operator shall conduct all monitoring in continuous operation at all times the

pollutant-specific emissions unit is operating.

40 CFR Section 64.7(c)

Minn. R. 7017.0200

Response to excursions or exceedances: Upon detecting an excursion or

exceedance, the owner or operator shall restore operation of the pollutant-specific

emissions unit to its normal or usual manner of operation as expeditiously as

practicable in accordance with good air pollution control practices for minimizing

emissions.

40 CFR Section 64.7(d)(1)

Minn. R. 7017.0200

Documentation of need for improved monitoring: After approval of monitoring

under this part, if the owner or operator identifies a failure to achieve compliance

with an emission limitation or standard for which the approved monitoring did not

provide an indication of an excursion or exceedance while providing valid data, or

the results of compliance or performance testing document a need to modify the

existing indicator ranges or designated conditions, the owner or operator shall

promptly notify the permitting authority and, if necessary, submit a proposed

modification to the part 70 permit to address the necessary monitoring changes.

40 CFR Section 64.7(e)

Minn. R. 7017.0200

The owner or operator shall maintain records of monitoring data, monitor

performance data, corrective actions taken, any written quality improvement plan

required pursuant to 64.8 and any activities undertaken to implement a quality

improvement plan, and other supporting information required to be maintained.

The owner or operator may maintain records on alternative media, such as

microfilm, computer files, magnetic tape disks, or microfiche, provided that the use

of such alternative media allows for expeditious inspection and review, and does

not conflict with other applicable recordkeeping requirements.

40 CFR Section 64.9(b)

Minn. R. 7017.0200

The owner or operator shall report exceedances or excursions under Section 64.7

and Section 64.8 when the exceedance or excursion are greater than the limit and

averaging period with the Semiannual Deviations Report.

40 CFR Section 64.9(a)(2)(i)

Minn. R. 7017.0200
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-43

Subject Item: CE 004 Venturi Scrubber

Associated Items: EU 004 Power Boiler 4

What to do Why to do it

A minimum of one venturi slurry pump for each particulate scrubber module in

service shall be operated at all times during the operation of EU004.

Title 1 Condition: monitoring for the particulate matter

emission limit set under 40 CFR Section 52.21 and 40

CFR Section 60.42(a)(1)

COMPLIANCE ASSURANCE MONITORING hdr

The owner or operator shall comply with the approved monitoring for opacity. The

owner or operator shall measure the opacity by means of a COM.

Parameter range indicating normal operation is opacity as a six-minute average

less than or equal to 20 percent opacity.

40 CFR Section 64.3(b) or (d)

40 CFR Section 64.6(c)(1)(i)

40 CFR Section 64.6)c)(1)(ii)

Minn. R. 7017.0200

The owner or operator shall conduct the monitoring required under this part upon

permit issuance.

40 CFR Section 64.7(a)

Minn. R. 7017.0200

The owner or operator shall maintain the monitoring instruments and recorders,

including but not limited to maintaining necessary parts for routine repairs of the

monitoring equipment.

40 CFR Section 64.7(b)

Minn. R. 7017.0200

Continuous Operation: Except for, as applicable, monitoring malfunctions,

associated repairs, and required quality assurance or control activities, the owner

or operator shall conduct all monitoring in continuous operation at all times the

pollutant-specific emissions unit is operating.

40 CFR Section 64.7(c)

Minn. R. 7017.0200

Response to excursions or exceedances: Upon detecting an excursion or

exceedance, the owner or operator shall restore operation of the pollutant-specific

emissions unit to its normal or usual manner of operation as expeditiously as

practicable in accordance with good air pollution control practices for minimizing

emissions.

40 CFR Section 64.7(d)(1)

Minn. R. 7017.0200

Documentation of need for improved monitoring: After approval of monitoring

under this part, if the owner or operator identifies a failure to achieve compliance

with an emission limitation or standard for which the approved monitoring did not

provide an indication of an excursion or exceedance while providing valid data, or

the results of compliance or performance testing document a need to modify the

existing indicator ranges or designated conditions, the owner or operator shall

promptly notify the permitting authority and, if necessary, submit a proposed

modification to the part 70 permit to address the necessary monitoring changes.

40 CFR Section 64.7(e)

Minn. R. 7017.0200

The owner or operator shall maintain records of monitoring data, monitor

performance data, corrective actions taken, any written quality improvement plan

required pursuant to 64.8 and any activities undertaken to implement a quality

improvement plan, and other supporting information required to be maintained.

The owner or operator may maintain records on alternative media, such as

microfilm, computer files, magnetic tape disks, or microfiche, provided that the use

of such alternative media allows for expeditious inspection and review, and does

not conflict with other applicable recordkeeping requirements.

40 CFR Section 64.9(b)

Minn. R. 7017.0200

The owner or operator shall report exceedances or excursions under Section 64.7

and Section 64.8 when the exceedance or excursion are greater than the limit and

averaging period with the Semiannual Deviations Report.

40 CFR Section 64.9(a)(2)(i)

Minn. R. 7017.0200
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-44

Subject Item: CE 005 Electrostatic Precipitator - High Efficiency

Associated Items: EU 004 Power Boiler 4

What to do Why to do it

When bypass reheat is required to maintain compliance with the minimum flue gas

exit temperature specified under SV004 in this permit, a portion of the total flue gas

from EU004 may bypass the particulate matter emissions scrubber (CE004) and

sulfur dioxide absorber (CE006), and be treated by a minimum of one unit of

CE005 (electrostatic precipitator). When required to operate, CE005 shall not be

operated with more than three of the bus-sections de-energized.

When bypass reheat is not required to maintain compliance with the minimum flue

gas exit temperature, all of the EU004 flue gas shall be treated by the particulate

matter emissions scrubber (CE004) and sulfur dioxide absorber (CE006). After

closing the inlet and outlet dampers to CE005, the Permittee may de-energize

CE005.

Title 1 Condition: To ensure compliance with the

particulate matter emission limit set under 40 CFR

Section 52.21 and 40 CFR Section 60.42(a)(1)

COMPLIANCE ASSURANCE MONITORING hdr

The owner or operator shall comply with the approved monitoring for opacity. The

owner or operator shall measure the opacity by means of a COM.

Parameter range indicating normal operation is opacity as a six-minute average

less than or equal to 20 percent opacity

40 CFR Section 64.3(b) or (d)

40 CFR Section 64.6(c)(1)(i)

40 CFR Section 64.6)c)(1)(ii)

Minn. R. 7017.0200

The owner or operator shall conduct the monitoring required under this part upon

permit issuance.

40 CFR Section 64.7(a)

Minn. R. 7017.0200

The owner or operator shall maintain the monitoring instruments and recorders,

including but not limited to maintaining necessary parts for routine repairs of the

monitoring equipment.

40 CFR Section 64.7(b)

Minn. R. 7017.0200

Continuous Operation: Except for, as applicable, monitoring malfunctions,

associated repairs, and required quality assurance or control activities, the owner

or operator shall conduct all monitoring in continuous operation at all times the

pollutant-specific emissions unit is operating.

40 CFR Section 64.7(c)

Minn. R. 7017.0200

Response to excursions or exceedances: Upon detecting an excursion or

exceedance, the owner or operator shall restore operation of the pollutant-specific

emissions unit to its normal or usual manner of operation as expeditiously as

practicable in accordance with good air pollution control practices for minimizing

emissions.

40 CFR Section 64.7(d)(1)

Minn. R. 7017.0200

Documentation of need for improved monitoring: After approval of monitoring

under this part, if the owner or operator identifies a failure to achieve compliance

with an emission limitation or standard for which the approved monitoring did not

provide an indication of an excursion or exceedance while providing valid data, or

the results of compliance or performance testing document a need to modify the

existing indicator ranges or designated conditions, the owner or operator shall

promptly notify the permitting authority and, if necessary, submit a proposed

modification to the part 70 permit to address the necessary monitoring changes.

40 CFR Section 64.7(e)

Minn. R. 7017.0200

The owner or operator shall maintain records of monitoring data, monitor

performance data, corrective actions taken, any written quality improvement plan

required pursuant to 64.8 and any activities undertaken to implement a quality

improvement plan, and other supporting information required to be maintained.

The owner or operator may maintain records on alternative media, such as

microfilm, computer files, magnetic tape disks, or microfiche, provided that the use

of such alternative media allows for expeditious inspection and review, and does

not conflict with other applicable recordkeeping requirements.

40 CFR Section 64.9(b)

Minn. R. 7017.0200

The owner or operator shall report exceedances or excursions under Section 64.7

and Section 64.8 when the exceedance or excursion are greater than the limit and

averaging period with the Semiannual Deviations Report.

40 CFR Section 64.9(a)(2)(i)

Minn. R. 7017.0200
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-45

Subject Item: CE 021 Fabric Filter - High Temperature, i.e., T>250 Degrees F

Associated Items: EU 003 Power Boiler 3

What to do Why to do it

The Permittee shall operate and maintain the control equipment such that it

achieves an overall control efficiency for Total Particulate Matter: greater than or

equal to 99 percent collection efficiency

Minn. R. 7007.0800, subp. 2 and 14

The Permittee shall operate and maintain the fabric filter in accordance with the

Operation and Maintenance (O & M) Plan. The Permittee shall keep copies of the

O & M Plan available onsite for use by staff and MPCA staff.

Minn. R. 7007.0800, subp. 14

Corrective Actions: The Permittee shall take corrective action as soon as possible if

any of the following occur:

- the recorded opacity is outside the permitted range; or

- the fabric filter or any of its components are found during the inspections to need

repair.

Corrective actions shall return the opacity to within the permitted range, and/or

include completion of necessary repairs identified during the inspection, as

applicable. Corrective actions include, but are not limited to, those outlined in the O

& M Plan for the fabric filter. The Permittee shall keep a record of the type and date

of any corrective action taken for each filter.

Minn. R. 7007.0800, subp. 4, 5, and 14

COMPLIANCE ASSURANCE MONITORING hdr

The owner or operator shall comply with the approved monitoring for opacity. The

owner or operator shall measure the opacity by means of a COM.

Parameter range indicating normal operation is opacity as a six-minute average

less than or equal to 20 percent opacity.

These requirements apply upon return of Unit 3 to regular operation.

40 CFR Section 64.3(b) or (d)

40 CFR Section 64.6(c)(1)(i)

40 CFR Section 64.6)c)(1)(ii)

Minn. R. 7017.0200

An excursion or exceedance from the specified parameter range occurs when:

1. the measured pressure drop (observed once per operating day) deviates from

the specified minimum or maximum by 0.1 inch WC or more.

40 CFR Section 64.6(c)(2)

The owner or operator shall conduct the monitoring required under this part upon

permit issuance.

40 CFR Section 64.7(a)

Minn. R. 7017.0200

The owner or operator shall maintain the monitoring instruments and recorders,

including but not limited to maintaining necessary parts for routine repairs of the

monitoring equipment.

40 CFR Section 64.7(b)

Minn. R. 7017.0200

Continuous Operation: Except for, as applicable, monitoring malfunctions,

associated repairs, and required quality assurance or control activities, the owner

or operator shall conduct all monitoring in continuous operation at all times the

pollutant-specific emissions unit is operating.

40 CFR Section 64.7(c)

Minn. R. 7017.0200

Response to excursions or exceedances: Upon detecting an excursion or

exceedance, the owner or operator shall restore operation of the pollutant-specific

emissions unit to its normal or usual manner of operation as expeditiously as

practicable in accordance with good air pollution control practices for minimizing

emissions.

40 CFR Section 64.7(d)(1)

Minn. R. 7017.0200

Documentation of need for improved monitoring: After approval of monitoring

under this part, if the owner or operator identifies a failure to achieve compliance

with an emission limitation or standard for which the approved monitoring did not

provide an indication of an excursion or exceedance while providing valid data, or

the results of compliance or performance testing document a need to modify the

existing indicator ranges or designated conditions, the owner or operator shall

promptly notify the permitting authority and, if necessary, submit a proposed

modification to the part 70 permit to address the necessary monitoring changes.

40 CFR Section 64.7(e)

Minn. R. 7017.0200

The owner or operator shall maintain records of monitoring data, monitor

performance data, corrective actions taken, any written quality improvement plan

required pursuant to 64.8 and any activities undertaken to implement a quality

improvement plan, and other supporting information required to be maintained.

The owner or operator may maintain records on alternative media, such as

microfilm, computer files, magnetic tape disks, or microfiche, provided that the use

of such alternative media allows for expeditious inspection and review, and does

not conflict with other applicable recordkeeping requirements.

40 CFR Section 64.9(b)

Minn. R. 7017.0200

The owner or operator shall report exceedances or excursions under 64.7 and 64.8

when the exceedance or excursion are greater than the limit and averaging period

with the Semiannual Deviations Report.

40 CFR Section 64.9(a)(2)(i)

Minn. R. 7017.0200
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-46

Subject Item: FS 004 Unpaved Roads

What to do Why to do it

OPERATING CONDITIONS

These requirements apply after 4/1/2007.

hdr

Fugitive Dust Control - EU003 dry fly ash haul roads:

- apply at least 3 gallons for each 100 square feet every 24 hours,

- a rainfall of at least 0.1 inch during the previous 24 hours shall substitute for one

water application,

- if the road cannot be watered because the ambient air temperature is less than 35

degrees F or if conditions due to weather, in combination with the application of

water, could create hazardous driving conditions, then watering shall be postponed

and accomplished as soon as the conditions preventing water application have

abated,

- water application is not required on days when there is no vehicle traffic, and

- following any day when water is not applied based on the absence of traffic, water

shall be applied within 3 hours of commencement of vehicle traffic, unless another

criterion for not watering is met.

Minn. R. 7011.0150

RECORDKEEPING hdr

Maintain daily records of:

- whether there was 0.1 inch or more of rainfall in the last 24 hours,

- temperature,

- if conditions exist where watering would create hazardous driving,

- dates of watering and areas watered, and

- amounts of water applied.

Minn. R. 7007.0800, subp. 4
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-47

Subject Item: FS 007 Paved Roads

What to do Why to do it

OPERATING REQUIREMENTS

These requirements apply after 4/1/2007.

hdr

Under dry pavement conditions, if the temperature is less than 35 degrees, or if

conditions due to weather in combination with the application of water, could create

hazardous driving conditions, paved plant roads shall be swept weekly. Sweeping

is not required if the pavement is snow or ice covered.

Under dry pavement conditions, if the temperature is greater than 35 degrees, and

conditions due to weather in combination with the application of water will not

create hazardous driving conditions, paved plant roads shall be swept and flushed

weekly.

Title I Condition: to avoid major modification

classification under 40 CFR Section 52.21 and Minn.

R. 7007.3000

RECORDKEEPING hdr

Maintain daily records of:

- whether and which areas are snow and ice covered,

- whether and which areas are dry,

- dates of sweeping and areas swept,

- dates of flushing and areas flushed, and

- amounts of water applied when flushing.

Minn. R. 7007.0800, subp. 4
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-48

Subject Item: MR 002 Blr 1, 2, and 3 SO2

Associated Items: EU 001 Power Boiler 1 

EU 002 Power Boiler 2 

EU 003 Power Boiler 3

GP 003 NOx and SO2 Monitors

What to do Why to do it

CONTINUOUS EMISSION MONITORING SYSTEMS (CEMS) Requirements

(additional requirements are located under the associated GP subject item and in

Table B.)

hdr

CEMS Relative Accuracy Test Audit (RATA): due before end of each calendar

half-year following CEM Certification Test, i.e., once every two successive QA

operating quarters (calendar quarter in which there are at least 168 unit operating

hours). Conduct a RATA on all CEMS required by the Acid Rain Program, in

accordance with 40 CFR pt. 75, Appendix B. Relative accuracy test audits may be

performed annually (i.e., once every four successive QA operating quarters, rather

than once every two successive QA operating quarters) if any of the conditions

listed in 40 CFR pt. 75, Appendix B, Section 2.3.1.2(a) through Section 2.3.1.2(i)

are met.

40 CFR pt. 75, Appendix B, section 2.3.1; Minn. R.

7017.1020

Relative Accuracy Test Audit (RATA) Results Summary: due 30 days after end of

each calendar half-year following CEMS Relative Accuracy Test Audit (RATA) in

which a CEMs RATA was conducted for MR002.

Minn. R. 7017.1180, subp. 3

Linearity and Leak Check Test (Acid Rain Program): due before end of each QA

operating quarter (as defined in Section 72.) in accordance with procedures in 40

CFR pt. 75, Appendix B, Sections 2.2.1 and 2.2.2, and Appendix A, Section 6.2.

Perform a leak check at least once during each QA operating quarter (calendar

quarter in which there are at least 168 unit operating hours) and no less than 30

days apart.

40 CFR pt. 75, Appendix B, section 2.2.1 & section

2.2.2; Minn. R. 7017.1020

Linearity Test Results Summary: due 30 days after end of each calendar quarter

following Linearity and Leak Check Test (Acid Rain Program), if performed.

Minn. R. 7007.0800, subp. 4
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-49

Subject Item: MR 004 Blr 1 and 2 NOx

Associated Items: EU 001 Power Boiler 1 

EU 002 Power Boiler 2 

GP 003 NOx and SO2 Monitors

What to do Why to do it

CONTINUOUS EMISSION MONITORING SYSTEMS (CEMS) Requirements

(additional requirements are located under the associated GP subject item and in

Table B.)

hdr

CEMS Relative Accuracy Test Audit (RATA): due before end of each calendar

half-year following CEM Certification Test, i.e., once every two successive QA

operating quarters (calendar quarter in which there are at least 168 unit operating

hours). Conduct a RATA on all CEMS required by the Acid Rain Program, in

accordance with 40 CFR pt. 75, Appendix B. Relative accuracy test audits may be

performed annually (i.e., once every four successive QA operating quarters, rather

than once every two successive QA operating quarters) if any of the conditions

listed in 40 CFR pt. 75, Appendix B, Section 2.3.1.2(a) through Section 2.3.1.2(i)

are met.

40 CFR pt. 75, Appendix B, section 2.3.1; Minn. R.

7017.1020

Relative Accuracy Test Audit (RATA) Results Summary: due 30 days after end of

each calendar half-year following CEMS Relative Accuracy Test Audit (RATA) in

which a CEMs RATA was conducted for MR002.

Minn. R. 7017.1180, subp. 3

Linearity and Leak Check Test (Acid Rain Program): due before end of each QA

operating quarter (as defined in Section 72.) in accordance with procedures in 40

CFR pt. 75, Appendix B, Sections 2.2.1 and 2.2.2, and Appendix A, Section 6.2.

Perform a leak check at least once during each QA operating quarter (calendar

quarter in which there are at least 168 unit operating hours) and no less than 30

days apart.

40 CFR pt. 75, Appendix B, section 2.2.1 & section

2.2.2; Minn. R. 7017.1020

Linearity Test Results Summary: due 30 days after end of each calendar quarter

following Linearity and Leak Check Test (Acid Rain Program), if performed.

Minn. R. 7007.0800, subp. 4
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-50

Subject Item: MR 007 Blr 4 SO2

Associated Items: CM 002 Boiler 4: 1.2 lbs SO2/mmBtu, EU004, 1-hr ave.

EU 004 Power Boiler 4

GP 003 NOx and SO2 Monitors

What to do Why to do it

CONTINUOUS EMISSION MONITORING SYSTEMS (CEMS) Requirements

(Additional requirements are located under the associated GP subject item and in

Table B.)

hdr

CEMS Relative Accuracy Test Audit (RATA): due before end of each calendar

half-year following CEM Certification Test for MR007, i.e., once every two

successive QA operating quarters (calendar quarter in which there are at least 168

unit operating hours). Conduct a RATA on all CEMS required by the Acid Rain

Program, in accordance with 40 CFR pt. 75, Appendix B. Relative accuracy test

audits may be performed annually (i.e., once every four successive QA operating

quarters, rather than once every two successive QA operating quarters) if any of

the conditions listed in 40 CFR pt. 75, Appendix B, Section 2.3.1.2(a) through

Section 2.3.1.2(i) are met.

40 CFR pt. 75, Appendix B, Section 2.3.1, Minn. R.

7017.1020

Linearity and Leak Check Test (Acid Rain Program): due before end of each QA

operating quarter (as defined in Section 72.) in accordance with procedures in 40

CFR pt. 75, Appendix B, Sections 2.2.1 and 2.2.2, and Appendix A, Section 6.2.

Perform a leak check at least once during each QA operating quarter (calendar

quarter in which there are at least 168 unit operating hours) and no less than 30

days apart.

40 CFR pt. 75, Appendix B, Section 2.2.1 & Section

2.2.2; Minn. R. 7017.1020
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-51

Subject Item: MR 008 Blr 4 NOx

Associated Items: CM 003 Boiler 4: 0.7 lbs NOx/mmBtu, EU004, 3-hr ave.

EU 004 Power Boiler 4

GP 003 NOx and SO2 Monitors

What to do Why to do it

CONTINUOUS EMISSION MONITORING SYSTEMS (CEMS) Requirements

(Additional requirements are located under the associated GP subject item and in

Table B.)

hdr

CEMS Relative Accuracy Test Audit (RATA): due before end of each calendar

half-year following CEM Certification Test for Monitor 008, i.e., once every two

successive QA operating quarters (calendar quarter in which there are at least 168

unit operating hours). Conduct a RATA on all CEMS required by the Acid Rain

Program, in accordance with 40 CFR pt. 75, Appendix B. Relative accuracy test

audits may be performed annually (i.e., once every four successive QA operating

quarters, rather than once every two successive QA operating quarters) if any of

the conditions listed in 40 CFR pt. 75, Appendix B, Section 2.3.1.2(a) through

Section 2.3.1.2(i) are met.

40 CFR pt. 75, Appendix B, Section 2.3.1, Minn. R.

7017.1020

Linearity and Leak Check Test (Acid Rain Program): due before end of each QA

operating quarter (as defined in Section 72.) in accordance with procedures in 40

CFR pt. 75, Appendix B, Sections 2.2.1 and 2.2.2, and Appendix A, Section 6.2.

Perform a leak check at least once during each QA operating quarter (calendar

quarter in which there are at least 168 unit operating hours) and no less than 30

days apart.

40 CFR pt. 75, Appendix B, Section 2.2.1 & Section

2.2.2; Minn. R. 7017.1020
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-52

Subject Item: MR 016 Blr 3 NOx

Associated Items: EU 003 Power Boiler 3

GP 003 NOx and SO2 Monitors

What to do Why to do it

CONTINUOUS EMISSION MONITORING SYSTEMS (CEMS) Requirements

(additional requirements are located under the associated GP subject item and in

Table B.)

hdr

CEMS Relative Accuracy Test Audit (RATA): due before end of each calendar

half-year following CEM Certification Test, i.e., once every two successive QA

operating quarters (calendar quarter in which there are at least 168 unit operating

hours). Conduct a RATA on all CEMS required by the Acid Rain Program, in

accordance with 40 CFR pt. 75, Appendix B. Relative accuracy test audits may be

performed annually (i.e., once every four successive QA operating quarters, rather

than once every two successive QA operating quarters) if any of the conditions

listed in 40 CFR pt. 75, Appendix B, Section 2.3.1.2(a) through Section 2.3.1.2(i)

are met.

40 CFR pt. 75, Appendix B, section 2.3.1; Minn. R.

7017.1020

Relative Accuracy Test Audit (RATA) Results Summary: due 30 days after end of

each calendar half-year following CEMS Relative Accuracy Test Audit (RATA) in

which a CEMs RATA was conducted for MR002.

Minn. R. 7017.1180, subp. 3

Linearity and Leak Check Test (Acid Rain Program): due before end of each QA

operating quarter (as defined in Section 72.) in accordance with procedures in 40

CFR pt. 75, Appendix B, Sections 2.2.1 and 2.2.2, and Appendix A, Section 6.2.

Perform a leak check at least once during each QA operating quarter (calendar

quarter in which there are at least 168 unit operating hours) and no less than 30

days apart.

40 CFR pt. 75, Appendix B, section 2.2.1 & section

2.2.2; Minn. R. 7017.1020

Linearity Test Results Summary: due 30 days after end of each calendar quarter

following Linearity and Leak Check Test (Acid Rain Program), if performed.

Minn. R. 7007.0800, subp. 4
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-53

Subject Item: MR 020 Blr 1 Opacity

Associated Items: CM 004 Boiler 1: 20% Opacity, EU001, 6-min ave.

EU 001 Power Boiler 1 

GP 002 Opacity Monitors

What to do Why to do it

CONTINUOUS OPACITY MONITORING SYSTEMS (COMS) Requirements

(Additional requirements are located under the associated GP subject item)

hdr

COMS Calibration Error Audit: due before end of each calendar half-year starting

03/28/2007 for MR020. Conduct three point calibration error audits at least 3

months apart but no greater than 8 months apart. Conduct audits in accordance

with Minn. R. 7017.1210, subp. 3.

Minn. R. 7017.1210, subp. 3
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-54

Subject Item: MR 021 Blr 2 Opacity

Associated Items: CM 005 Boiler 2: 20% Opacity, EU002, 6-min ave.

EU 002 Power Boiler 2 

GP 002 Opacity Monitors

What to do Why to do it

CONTINUOUS OPACITY MONITORING SYSTEMS (COMS) Requirements

(Additional requirements are located under the associated GP subject item and in

Table B.)

hdr

COMS Calibration Error Audit: due before end of each calendar half-year starting

03/28/2007 for MR021. Conduct three point calibration error audits at least 3

months apart but no greater than 8 months apart. Conduct audits in accordance

with Minn. R. 7017.1210, subp. 3.

Minn. R. 7017.1210, subp. 3
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-55

Subject Item: MR 024 Boiler 3 CO

Associated Items: EU 003 Power Boiler 3

What to do Why to do it

CONTINUOUS EMISSION MONITORING SYSTEMS (CEMS) Requirements

(Additional requirements are located in Table B.)

hdr

CEMS Relative Accuracy Test Audit (RATA): due before end of each year following

CEM Certification Test for MR024. A RATA is not required in any calendar year if a

RATA conducted in the previous year demonstrated a relative accuracy value of

less than 15 percent or if the associated emissions unit operated less than 48

hours during the calendar year. If the exception is used, the next RATA shall be

conducted during the first half of the following calendar year. RATAs shall be

conducted at least 3 months apart according to 40 CFR pt. 60, Appendix F, section

5.1.1.

Minn. R. 7017.1170, subp. 5

Relative Accuracy Test Audit (RATA) Notification: due 30 days before CEMS

Relative Accuracy Test Audit (RATA)).

Minn. R. 7017.1180, subp. 2

Recordkeeping: The owner or operator must retain records of all CEMS monitoring

data and support information for a period of five years from the date of the

monitoring sample, measurement or report. Records shall be kept at the source.

Minn. R. 7017.1130

Continuous Operation: CEMS must be operated and data recorded during all

periods of emission unit operation including periods of emission unit start-up,

shutdown, or malfunction except for periods of acceptable monitor downtime. This

requirement applies whether or not a numerical emission limit applies during these

periods. A CEMS must not be bypassed except in emergencies where failure to

bypass would endanger human health, safety, or plant equipment.

Minn. R. 7017.1090
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-56

Subject Item: MR 025 Blr 3 Mercury

Associated Items: EU 003 Power Boiler 3

GP 006 Boilers 3 and 4 Mercury Monitors

What to do Why to do it

CONTINUOUS EMISSION MONITORING SYSTEMS (CEMS) Requirements:

(Additional requirements are located under the Subject Item EU 003 and in Table

B.)

hdr

CEMS QA/QC: The owner or operator shall meet the applicable QA/QC

requirements in 40 CFR Section 75.80(e) or as approved by the MPCA.

Minn. Stat. 216B.681

CEMS Relative Accuracy Test Audit (RATA): due before end of each year following

CEM Certification Test A RATA is not required in any calendar year if a RATA

conducted in the previous year demonstrated a relative accuracy value of less than

15 percent or if the associated emissions unit operated less than 48 hours during

the calendar year. If the exception is used, the next RATA shall be conducted

during the first half of the following calendar year. RATAs may be conducted using

an alternate test method as approved by the MPCA.

40 CFR Section 75.80(e); Minn. R. 7017.1170, subp. 5

Recordkeeping and Recording: Follow the provisions listed under 40 CFR Section

75.84. This requirement is effective beginning January 1, 2009.

Minn. Stat. 216B.681
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-57

Subject Item: MR 026 Blr 4 Mercury

Associated Items: EU 004 Power Boiler 4

GP 006 Boilers 3 and 4 Mercury Monitors

What to do Why to do it

CONTINUOUS EMISSION MONITORING SYSTEMS (CEMS) Requirements

(Additional requirements are found under the Subject Item EU 004 and in Table B)

hdr

CEMS QA/QC: The owner or operator shall meet the applicable QA/QC

requirements in 40 CFR Section 75.80(e) or as approved by the MPCA.

Minn. Stat. 216B.681

CEMS Relative Accuracy Test Audit (RATA): due before end of each year starting

03/28/2007 A RATA is not required in any calendar year if a RATA conducted in the

previous year demonstrated a relative accuracy value of less than 15 percent or if

the associated emissions unit operated less than 48 hours during the calendar

year. If the exception is used, the next RATA shall be conducted during the first

half of the following calendar year. RATAs may be conducted using an alternative

test method as approved by the MPCA.

40 CFR Section 75.80(e); Minn. R. 7017.1170, subp. 5

Recordkeeping and Recording: Follow the provisions listed under 40 CFR Section

75.84. This requirement is effective beginning January 1, 2009.

Minn. Stat. 216B.681
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-58

Subject Item: MR 027 Boiler 3 Opacity

Associated Items: EU 003 Power Boiler 3

GP 002 Opacity Monitors

What to do Why to do it

CONTINUOUS OPACITY MONITORING SYSTEMS (COMS) Requirements

(Additional requirements are located under the associated GP subject item and in

Table B.)

hdr

COMS Calibration Error Audit: due before end of each calendar half-year following

COMS Certification Test for MR027. Conduct three point calibration error audits at

least 3 months apart but no greater than 8 months apart. Conduct audits in

accordance with Minn. R. 7017.1210, subp. 3.

Minn. R. 7017.1210, subp. 3

REQUIREMENTS FOR INSTALLATION OF MR027, BOILER 3 FOR OPACITY. hdr

COMS Certification Test Pretest Meeting: due 7 days before COMS Certification

Test.

Minn. R. 7017.1060, subp. 3

COMS Certification Test: due 60 days after achieving maximum capacity. Minn. R. 7017.1050, subp.1

COMS Certification Test Report: due 45 days after COMS Certification Test. Minn. R. 7017.1080, subp. 1, 2 & 4

COMS Certification Test Report - Microfiche or CD Copy: due 105 days after

COMS Certification Test.

Minn. R. 7017.1080, subp. 3
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-59

Subject Item: MR 028 Blr 1 SO2

Associated Items: CM 009 Boilers 1, 2 & 3: SO2, 1-hr ave.

EU 001 Power Boiler 1 

GP 003 NOx and SO2 Monitors

What to do Why to do it

CONTINUOUS EMISSION MONITORING SYSTEMS (CEMS) Requirements

(additional requirements are located under the associated GP subject item and in

Table B.)

hdr

CEMS Relative Accuracy Test Audit (RATA): due before end of each calendar

half-year following CEM Certification Test, i.e., once every two successive QA

operating quarters (calendar quarter in which there are at least 168 unit operating

hours). Conduct a RATA on all CEMS required by the Acid Rain Program, in

accordance with 40 CFR pt. 75, Appendix B. Relative accuracy test audits may be

performed annually (i.e., once every four successive QA operating quarters, rather

than once every two successive QA operating quarters) if any of the conditions

listed in 40 CFR pt. 75, Appendix B, Section 2.3.1.2(a) through Section 2.3.1.2(i)

are met.

40 CFR pt. 75, Appendix B, section 2.3.1; Minn. R.

7017.1020

Linearity and Leak Check Test (Acid Rain Program): due before end of each QA

operating quarter (as defined in Section 72.) in accordance with procedures in 40

CFR pt. 75, Appendix B, Sections 2.2.1 and 2.2.2, and Appendix A, Section 6.2.

Perform a leak check at least once during each QA operating quarter (calendar

quarter in which there are at least 168 unit operating hours) and no less than 30

days apart.

40 CFR pt. 75, Appendix B, section 2.2.1 & section

2.2.2; Minn. R. 7017.1020

CEM Certification Test: due 60 days after achieving normal operation but not later

than 180 days after initial startup or within 90 days after the due date of the first

excess emissions report, whichever is more stringent.

Minn. R. 7017.1050, subp. 1

CEMS Certification Test Plan: due 30 days before CEMS Certification Test. Minn. R. 7017.1080, subp. 1, 2, & 4

CEMS Certification Test Pretest Meeting: due 7 days before CEMS Certification

Test.

Minn. R. 7017.1060, subp. 3

CEMS Certification Test Report - Microfiche or CD Copy: due 105 days after

CEMS Certification Test.

Minn. R. 7017.1080, subp. 3

CEMS Certification Test Report - Microfiche or CD Copy: due 105 days after

CEMS Certification Test.

Minn. R. 7017.1080, subp. 3
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-60

Subject Item: MR 029 Blr 1 NOx

Associated Items: CM 010 Boilers 1 & 2: NOx Title IV

EU 001 Power Boiler 1 

GP 003 NOx and SO2 Monitors

What to do Why to do it

CONTINUOUS EMISSION MONITORING SYSTEMS (CEMS) Requirements

(additional requirements are located under the associated GP subject item and in

Table B.)

hdr

CEMS Relative Accuracy Test Audit (RATA): due before end of each calendar

half-year following CEM Certification Test, i.e., once every two successive QA

operating quarters (calendar quarter in which there are at least 168 unit operating

hours). Conduct a RATA on all CEMS required by the Acid Rain Program, in

accordance with 40 CFR pt. 75, Appendix B. Relative accuracy test audits may be

performed annually (i.e., once every four successive QA operating quarters, rather

than once every two successive QA operating quarters) if any of the conditions

listed in 40 CFR pt. 75, Appendix B, Section 2.3.1.2(a) through Section 2.3.1.2(i)

are met.

40 CFR pt. 75, Appendix B, section 2.3.1; Minn. R.

7017.1020

Linearity and Leak Check Test (Acid Rain Program): due before end of each QA

operating quarter (as defined in Section 72.) in accordance with procedures in 40

CFR pt. 75, Appendix B, Sections 2.2.1 and 2.2.2, and Appendix A, Section 6.2.

Perform a leak check at least once during each QA operating quarter (calendar

quarter in which there are at least 168 unit operating hours) and no less than 30

days apart.

40 CFR pt. 75, Appendix B, section 2.2.1 & section

2.2.2; Minn. R. 7017.1020

CEM Certification Test: due 60 days after achieving normal operation but not later

than 180 days after initial startup or within 90 days after the due date of the first

excess emissions report, whichever is more stringent.

Minn. R. 7017.1050, subp. 1

CEMS Certification Test Plan: due 30 days before CEMS Certification Test. Minn. R. 7017.1080, subp. 1, 2, & 4

CEMS Certification Test Pretest Meeting: due 7 days before CEMS Certification

Test.

Minn. R. 7017.1060, subp. 3

CEMS Certification Test Report - Microfiche or CD Copy: due 105 days after

CEMS Certification Test.

Minn. R. 7017.1080, subp. 3

CEMS Certification Test Report - Microfiche or CD Copy: due 105 days after

CEMS Certification Test.

Minn. R. 7017.1080, subp. 3
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-61

Subject Item: MR 032 Blr 2 SO2

Associated Items: CM 009 Boilers 1, 2 & 3: SO2, 1-hr ave.

EU 002 Power Boiler 2 

GP 003 NOx and SO2 Monitors

What to do Why to do it

CONTINUOUS EMISSION MONITORING SYSTEMS (CEMS) Requirements

(additional requirements are located under the associated GP subject item and in

Table B.)

hdr

CEMS Relative Accuracy Test Audit (RATA): due before end of each calendar

half-year following CEM Certification Test, i.e., once every two successive QA

operating quarters (calendar quarter in which there are at least 168 unit operating

hours). Conduct a RATA on all CEMS required by the Acid Rain Program, in

accordance with 40 CFR pt. 75, Appendix B. Relative accuracy test audits may be

performed annually (i.e., once every four successive QA operating quarters, rather

than once every two successive QA operating quarters) if any of the conditions

listed in 40 CFR pt. 75, Appendix B, Section 2.3.1.2(a) through Section 2.3.1.2(i)

are met.

40 CFR pt. 75, Appendix B, section 2.3.1; Minn. R.

7017.1020

Linearity and Leak Check Test (Acid Rain Program): due before end of each QA

operating quarter (as defined in Section 72.) in accordance with procedures in 40

CFR pt. 75, Appendix B, Sections 2.2.1 and 2.2.2, and Appendix A, Section 6.2.

Perform a leak check at least once during each QA operating quarter (calendar

quarter in which there are at least 168 unit operating hours) and no less than 30

days apart.

40 CFR pt. 75, Appendix B, section 2.2.1 & section

2.2.2; Minn. R. 7017.1020

CEM Certification Test: due 60 days after achieving normal operation but not later

than 180 days after initial startup or within 90 days after the due date of the first

excess emissions report, whichever is more stringent.

Minn. R. 7017.1050, subp. 1

CEMS Certification Test Plan: due 30 days before CEMS Certification Test. Minn. R. 7017.1080, subp. 1, 2, & 4

CEMS Certification Test Pretest Meeting: due 7 days before CEMS Certification

Test.

Minn. R. 7017.1060, subp. 3

CEMS Certification Test Report - Microfiche or CD Copy: due 105 days after

CEMS Certification Test.

Minn. R. 7017.1080, subp. 3

CEMS Certification Test Report - Microfiche or CD Copy: due 105 days after

CEMS Certification Test.

Minn. R. 7017.1080, subp. 3
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-62

Subject Item: MR 033 Blr 2 NOx

Associated Items: CM 010 Boilers 1 & 2: NOx Title IV

EU 002 Power Boiler 2 

GP 003 NOx and SO2 Monitors

What to do Why to do it

CONTINUOUS EMISSION MONITORING SYSTEMS (CEMS) Requirements

(additional requirements are located under the associated GP subject item and in

Table B.)

hdr

CEMS Relative Accuracy Test Audit (RATA): due before end of each calendar

half-year following CEM Certification Test, i.e., once every two successive QA

operating quarters (calendar quarter in which there are at least 168 unit operating

hours). Conduct a RATA on all CEMS required by the Acid Rain Program, in

accordance with 40 CFR pt. 75, Appendix B. Relative accuracy test audits may be

performed annually (i.e., once every four successive QA operating quarters, rather

than once every two successive QA operating quarters) if any of the conditions

listed in 40 CFR pt. 75, Appendix B, Section 2.3.1.2(a) through Section 2.3.1.2(i)

are met.

40 CFR pt. 75, Appendix B, section 2.3.1; Minn. R.

7017.1020

Linearity and Leak Check Test (Acid Rain Program): due before end of each QA

operating quarter (as defined in Section 72.) in accordance with procedures in 40

CFR pt. 75, Appendix B, Sections 2.2.1 and 2.2.2, and Appendix A, Section 6.2.

Perform a leak check at least once during each QA operating quarter (calendar

quarter in which there are at least 168 unit operating hours) and no less than 30

days apart.

40 CFR pt. 75, Appendix B, section 2.2.1 & section

2.2.2; Minn. R. 7017.1020

CEM Certification Test: due 60 days after achieving normal operation but not later

than 180 days after initial startup or within 90 days after the due date of the first

excess emissions report, whichever is more stringent.

Minn. R. 7017.1050, subp. 1

CEMS Certification Test Plan: due 30 days before CEMS Certification Test. Minn. R. 7017.1080, subp. 1, 2, & 4

CEMS Certification Test Pretest Meeting: due 7 days before CEMS Certification

Test.

Minn. R. 7017.1060, subp. 3

CEMS Certification Test Report - Microfiche or CD Copy: due 105 days after

CEMS Certification Test.

Minn. R. 7017.1080, subp. 3

CEMS Certification Test Report - Microfiche or CD Copy: due 105 days after

CEMS Certification Test.

Minn. R. 7017.1080, subp. 3
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-63

Subject Item: MR 036 Blr 3 SO2

Associated Items: CM 009 Boilers 1, 2 & 3: SO2, 1-hr ave.

EU 003 Power Boiler 3

GP 003 NOx and SO2 Monitors

What to do Why to do it

CONTINUOUS EMISSION MONITORING SYSTEMS (CEMS) Requirements

(additional requirements are located under the associated GP subject item and in

Table B.)

hdr

CEMS Relative Accuracy Test Audit (RATA): due before end of each calendar

half-year following CEM Certification Test, i.e., once every two successive QA

operating quarters (calendar quarter in which there are at least 168 unit operating

hours). Conduct a RATA on all CEMS required by the Acid Rain Program, in

accordance with 40 CFR pt. 75, Appendix B. Relative accuracy test audits may be

performed annually (i.e., once every four successive QA operating quarters, rather

than once every two successive QA operating quarters) if any of the conditions

listed in 40 CFR pt. 75, Appendix B, Section 2.3.1.2(a) through Section 2.3.1.2(i)

are met.

40 CFR pt. 75, Appendix B, section 2.3.1; Minn. R.

7017.1020

Linearity and Leak Check Test (Acid Rain Program): due before end of each QA

operating quarter (as defined in Section 72.) in accordance with procedures in 40

CFR pt. 75, Appendix B, Sections 2.2.1 and 2.2.2, and Appendix A, Section 6.2.

Perform a leak check at least once during each QA operating quarter (calendar

quarter in which there are at least 168 unit operating hours) and no less than 30

days apart.

40 CFR pt. 75, Appendix B, section 2.2.1 & section

2.2.2; Minn. R. 7017.1020

CEM Certification Test: due 60 days after achieving normal operation but not later

than 180 days after initial startup or within 90 days after the due date of the first

excess emissions report, whichever is more stringent.

Minn. R. 7017.1050, subp. 1

CEMS Certification Test Plan: due 30 days before CEMS Certification Test. Minn. R. 7017.1080, subp. 1, 2, & 4

CEMS Certification Test Pretest Meeting: due 7 days before CEMS Certification

Test.

Minn. R. 7017.1060, subp. 3

CEMS Certification Test Report - Microfiche or CD Copy: due 105 days after

CEMS Certification Test.

Minn. R. 7017.1080, subp. 3

CEMS Certification Test Report - Microfiche or CD Copy: due 105 days after

CEMS Certification Test.

Minn. R. 7017.1080, subp. 3
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-64

Subject Item: MR 037 Blr 3 NOx

Associated Items: CM 008 Boiler 3, Title IV NOx

EU 003 Power Boiler 3

GP 003 NOx and SO2 Monitors

What to do Why to do it

CONTINUOUS EMISSION MONITORING SYSTEMS (CEMS) Requirements

(additional requirements are located under the associated GP subject item and in

Table B.)

hdr

CEMS Relative Accuracy Test Audit (RATA): due before end of each calendar

half-year following CEM Certification Test, i.e., once every two successive QA

operating quarters (calendar quarter in which there are at least 168 unit operating

hours). Conduct a RATA on all CEMS required by the Acid Rain Program, in

accordance with 40 CFR pt. 75, Appendix B. Relative accuracy test audits may be

performed annually (i.e., once every four successive QA operating quarters, rather

than once every two successive QA operating quarters) if any of the conditions

listed in 40 CFR pt. 75, Appendix B, Section 2.3.1.2(a) through Section 2.3.1.2(i)

are met.

40 CFR pt. 75, Appendix B, section 2.3.1; Minn. R.

7017.1020

Linearity and Leak Check Test (Acid Rain Program): due before end of each QA

operating quarter (as defined in Section 72.) in accordance with procedures in 40

CFR pt. 75, Appendix B, Sections 2.2.1 and 2.2.2, and Appendix A, Section 6.2.

Perform a leak check at least once during each QA operating quarter (calendar

quarter in which there are at least 168 unit operating hours) and no less than 30

days apart.

40 CFR pt. 75, Appendix B, section 2.2.1 & section

2.2.2; Minn. R. 7017.1020

CEM Certification Test: due 60 days after achieving normal operation but not later

than 180 days after initial startup or within 90 days after the due date of the first

excess emissions report, whichever is more stringent.

Minn. R. 7017.1050, subp. 1

CEMS Certification Test Plan: due 30 days before CEMS Certification Test. Minn. R. 7017.1080, subp. 1, 2, & 4

CEMS Certification Test Pretest Meeting: due 7 days before CEMS Certification

Test.

Minn. R. 7017.1060, subp. 3

CEMS Certification Test Report - Microfiche or CD Copy: due 105 days after

CEMS Certification Test.

Minn. R. 7017.1080, subp. 3

CEMS Certification Test Report - Microfiche or CD Copy: due 105 days after

CEMS Certification Test.

Minn. R. 7017.1080, subp. 3
TABLE A: LIMITS AND OTHER REQUIREMENTS 08/12/09

Minnesota Power Inc - Boswell Energy Ctr

06100004 - 004

Facility Name:

Permit Number:

A-65

Subject Item: MR 040 Blr 4 Opacity

Associated Items: EU 004 Power Boiler 4

GP 002 Opacity Monitors

What to do Why to do it

CONTINUOUS OPACITY MONITORING SYSTEMS (COMS) Requirements

(Additional requirements are located under the associated GP subject item and in

Table B.)

hdr

COMS Calibration Error Audit: due before end of each calendar half-year following

COMS Certification Test for MR040. Conduct three point calibration error audits at

least 3 months apart but no greater than 8 months apart. Conduct audits in

accordance with Minn. R. 7017.1210, subp. 3.

Minn. R. 7017.1210, subp. 3

TABLE B: SUBMITTALS

Facility Name: Minnesota Power Inc - Boswell Energy Ctr

Permit Number: 06100004 - 004

B-1 08/12/09

Also, where required by an applicable rule or permit condition, send to the Permit Technical Advisor notices of:

- accumulated insignificant activities,

- installation of control equipment,

- replacement of an emissions unit, and

- changes that contravene a permit term.

Send submittals that are required to be submitted to the U.S. EPA regional office to:

 Mr. George Czerniak

 Air and Radiation Branch

 EPA Region V

 77 West Jackson Boulevard

 Chicago, Illinois 60604

Unless another person is identified in the applicable Table, send all other submittals to:

 AQ Compliance Tracking Coordinator

 Industrial Division

 Minnesota Pollution Control Agency

 520 Lafayette Road North

 St. Paul, Minnesota 55155-4194

Send submittals that are required by the Acid Rain Program to:

 U.S. Environmental Protection Agency

 Clean Air Markets Division

 1200 Pennsylvania Avenue NW (6204N)

 Washington, D.C. 20460

Send any application for a permit or permit amendment to:

 AQ Permit Technical Advisor

 Industrial Division

 Minnesota Pollution Control Agency

 520 Lafayette Road North

 St. Paul, Minnesota 55155-4194

Each submittal must be postmarked or received by the date specified in the applicable Table. Those submittals required by parts

7007.0100 to 7007.1850 must be certified by a responsible official, defined in Minn. R. 7007.0100, subp. 21. Other submittals shall

be certified as appropriate if certification is required by an applicable rule or permit condition.

Table B lists most of the submittals required by this permit. Please note that some submittal requirements may appear in Table A

or, if applicable, within a compliance schedule located in Table C. Table B is divided into two sections in order to separately list

one-time only and recurrent submittal requirements.
TABLE B: ONE TIME SUBMITTALS OR NOTIFICATIONS

Facility Name: Minnesota Power Inc - Boswell Energy Ctr

Permit Number: 06100004 - 004

B-2 08/12/09

What to send When to send Portion of Facility Affected

Application for Permit Reissuance due 180 days before expiration of Existing

Permit

Total Facility

COMS Certification Test Notification due 30 days before COMS Certification Test

for MR027, Boiler 3 Opacity.

MR027

Notification of the Actual Date of Initial Startup due 15 days after Initial Startup after

modification of Boiler 3 and its pollution

control equipment stream.

EU003

Plans and Specifications due before 07/01/2011 for mercury removal.

The plan shall contain the information

specified in Minn. Stat. 216B.682, subd. 3.

EU004

Testing Frequency Plan due 60 days after Initial Performance Test for

Hydrogen Fluoride emissions.

EU003

Testing Frequency Plan due 60 days after Initial Performance Test for

Lead emissions.

EU003

Testing Frequency Plan due 60 days after Initial Performance Test for

PM and PM10 emissions.

EU003
TABLE B: RECURRENT SUBMITTALS

Facility Name: Minnesota Power Inc - Boswell Energy Ctr

Permit Number: 06100004 - 004

B-3 08/12/09

What to send When to send Portion of Facility Affected

Excess Emissions/Downtime Reports (EER's) due 30 days after end of each calendar

quarter following Initial Startup of the Monitor

(Submit Deviations Reporting Form DRF-1 as

amended). The EER must contain all of the

information requested in 40 CFR60.7(c). The

EER shall indicate all periods of monitor

bypass and all periods of exceedances of the

limit including exceedances allowed by an

applicable standard, i.e. during startup,

shutdown, and malfunctions.

GP002, GP003, MR024

Linearity Test Results Summary due 30 days after end of each calendar

quarter following CEM Certification Test in

which a Linearity and Leak Check Test was

conducted.

MR028, MR029, MR032, MR033, MR036,

MR037

Linearity Test Results Summary due 30 days after end of each calendar

quarter following Linearity and Leak Check

Test (Acid Rain Program), if performed.

MR007, MR008

Quarterly Report due 30 days after end of each calendar

quarter starting 01/01/2009 as referenced by

40 CFR Section 75.84(f).

MR026

Quarterly Report due 30 days after end of each calendar

quarter starting 01/01/2009 as required by 40

CFR Section 75.84(f).

MR025

Relative Accuracy Test Audit (RATA) Results

Summary

 due 30 days after end of each calendar

quarter following CEM Certification Test in

which the CEMS RATA was conducted.

MR028, MR029, MR032, MR033, MR036,

MR037

Relative Accuracy Test Audit (RATA) Results

Summary

 due 30 days after end of each calendar

quarter following CEMS Relative Accuracy

Test Audit (RATA)

MR025, MR026

COMS Calibration Error Audit Results

Summary

 due 30 days after end of each calendar

half-year following COMS Certification Test for

MR027, Boiler 3 Opacity.

MR027

COMS Calibration Error Audit Results

Summary

 due 30 days after end of each calendar

half-year following COMS Certification Test for

MR040, Boiler 3 Opacity.

MR040

COMS Calibration Error Audit Results

Summary

 due 30 days after end of each calendar

half-year starting 03/28/2007 for MR 020,

Boiler 1 Opacity.

MR020

COMS Calibration Error Audit Results

Summary

 due 30 days after end of each calendar

half-year starting 03/28/2007 for MR 021,

Boiler 2 Opacity.

MR021

Relative Accuracy Test Audit (RATA) Results

Summary

 due 30 days after end of each calendar

half-year following CEMS Relative Accuracy

Test Audit (RATA) in which the CEMs RATA

was conducted for MR007, Boiler 4 SO2.

MR007

Relative Accuracy Test Audit (RATA) Results

Summary

 due 30 days after end of each calendar

half-year following CEMS Relative Accuracy

Test Audit (RATA) in which the CEMs RATA

was conducted for MR008, Boiler 4 NOx.

MR008

Semiannual Deviations Report due 30 days after end of each calendar

half-year starting 03/28/2007. The first

semiannual report submitted by the Permittee

shall cover the calendar half-year in which the

permit is issued. The first report of each

calendar year covers January 1 - June 30.

The second report of each calendar year

covers July 1 - December 31. If no deviations

have occurred, the Permittee shall submit the

report stating no deviations.

Total Facility

Compliance Certification due 31 days after end of each calendar year

starting 03/28/2007 (for the previous calendar

year). To be submitted on a form approved by

the Commissioner, both to the Commissioner

and to the US EPA regional office in Chicago.

This report covers all deviations experienced

during the calendar year.

Total Facility
TABLE B: RECURRENT SUBMITTALS

Facility Name: Minnesota Power Inc - Boswell Energy Ctr

Permit Number: 06100004 - 004

B-4 08/12/09

Relative Accuracy Test Audit (RATA) Results

Summary

 due 30 days after end of each calendar year

following CEMS Relative Accuracy Test Audit

(RATA) in which the CEMs RATA was

conducted for MR024, Boiler 3 CO.

MR024
APPENDIX A 

Insignificant Activities 

Minnesota Power - Boswell Energy Center 

Permit Number: 06100004-004 

Insignificant Activities 

Activity Rule Citation Applicable 

Regulations 

Grinders Minn. R. 7007.1300, subp. 3.D.(2) Minn. R. 7011.0715 

Gasoline Tanks Minn. R. 7007.1300, subp. 3.E(1) NA 

Welding Equipment Minn. R. 7007.1300, subp. 3.H(4) Minn. R. 7011.0715 

Sandblasting Minn. R. 7007.1300, subp. 4.B(2) Minn. R. 7011.0715 

Coal Stockpile loading “ Minn. R. 7011.0150 

Coal Stockpile, 

equipment traffic 

“ Minn. R. 7011.0150 

Conveyor drop onto 

stockpile, reclaimer 

“ Minn. R. 7011.0150 

Conveyor Drop onto 

Stockpile –Side Chute 

“ Minn. R. 7011.0150 

Rail Car Unloading “ Minn. R. 7011.0150 

Rail Car Load Out “ Minn. R. 7011.0150 

Lab Hoods (4) “ Minn. R. 7011.0715 

Coal Transfer Tower A “ Minn. R. 7011.0150 

Coal Transfer Tower B “ Minn. R. 7011.0150 

Coal Conveyer Belt C3 “ Minn. R. 7011.0150 

Coal Rotary Car Dumper “ Minn. R. 7011.0150 

Coal Rotary Car TP “ Minn. R. 7011.0150 

Coal Transfer and 

Sampling House 

“ Minn. R. 7011.0150 

Coal Storage Silo “ Minn. R. 7011.0715 

Coal Tripper Transfer “ Minn. R. 7011.0715 

#4 Coal Bunker “ Minn. R. 7011.0715 

APPENDIX B 

Dispersion Modeling Parameters 

Minnesota Power - Boswell Energy Center 

Permit Number: 06100004-004 

Dispersion Modeling Parameters 

 *** N01 Itr 2; INL-INL, MN Metdata 1987 *** **MODELOPTs: CONC DFAULT ELEV  *** POINT SOURCE DATA ***  NUMBER EMISSION RATE BASE STACK STACK STACK STACK BLDG URBAN  SOURCE PART. (GRAMS/SEC) X Y ELEV. HEIGHT TEMP. EXIT VEL. DIAMETER EXISTS SOURCE  ID CATS. (METERS) (METERS) (METERS) (METERS) (DEG.K) (M/SEC) (METERS) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -  BEC_SV03 0 0.11653E+03 450543.2 5234354.5 392.6 192.44 361.48 12.64 8.84 YES NO  BEC_SV04 0 0.25749E+03 450653.8 5234624.5 394.6 170.31 343.15 35.85 6.10 YES NO  BEC_SV09 0 0.63000E-01 450631.3 5234411.0 396.2 13.72 699.82 20.21 0.24 YES NO  BEC_SV10 0 0.60480E+01 450683.1 5234583.0 395.4 8.23 699.82 8.80 0.64 YES NO  BEC_SV22 0 0.60000E-02 450555.3 5234413.5 394.3 9.14 847.04 10.49 0.20 YES NO  *** THE SUMMARY OF MAXIMUM PERIOD ( 8760 HRS) RESULTS ***  ** CONC OF NOX IN MICROGRAMS/M**3 ** GROUP ID AVERAGE CONC RECEPTOR (XR, YR, ZELEV, ZHILL, ZFLAG) OF TYPE GRI- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ALL 1ST HIGHEST VALUE IS 59.05281 AT ( 450572.66, 5234629.00, 392.04, 392.04, 0.00) DC  *** N04 Itr 2; INL-INL, MN Metdata 1987 *** **MODELOPTs: CONC DFAULT ELEV  *** POINT SOURCE DATA ***  NUMBER EMISSION RATE BASE STACK STACK STACK STACK BLDG URBAN  SOURCE PART. (GRAMS/SEC) X Y ELEV. HEIGHT TEMP. EXIT VEL. DIAMETER EXISTS SOURCE  ID CATS. (METERS) (METERS) (METERS) (METERS) (DEG.K) (M/SEC) (METERS) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -  BEC_SV03 0 0.29590E+02 450543.2 5234354.5 392.6 192.44 329.26 8.50 8.84 YES NO 
APPENDIX B 

Dispersion Modeling Parameters 

Minnesota Power - Boswell Energy Center 

Permit Number: 06100004-004 

 BEC_SV04 0 0.25749E+03 450653.8 5234624.5 394.6 170.31 343.15 35.85 6.10 YES NO  BEC_SV09 0 0.63000E-01 450631.3 5234411.0 396.2 13.72 699.82 20.21 0.24 YES NO  BEC_SV10 0 0.60480E+01 450683.1 5234583.0 395.4 8.23 699.82 8.80 0.64 YES NO  BEC_SV22 0 0.60000E-02 450555.3 5234413.5 394.3 9.14 847.04 10.49 0.20 YES NO  *** THE SUMMARY OF MAXIMUM PERIOD ( 8760 HRS) RESULTS ***  ** CONC OF NOX IN MICROGRAMS/M**3 ** GROUP ID AVERAGE CONC RECEPTOR (XR, YR, ZELEV, ZHILL, ZFLAG) OF TYPE GRI- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ALL 1ST HIGHEST VALUE IS 59.05276 AT ( 450572.66, 5234629.00, 392.04, 392.04, 0.00) DC  *** P01 Itr 2; INL-INL, MN Metdata 1990 *** **MODELOPTs: CONC DFAULT ELEV MULTYR  *** POINT SOURCE DATA ***  NUMBER EMISSION RATE BASE STACK STACK STACK STACK BLDG URBAN  SOURCE PART. (GRAMS/SEC) X Y ELEV. HEIGHT TEMP. EXIT VEL. DIAMETER EXISTS SOURCE  ID CATS. (METERS) (METERS) (METERS) (METERS) (DEG.K) (M/SEC) (METERS) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -  BEC_SV03 0 0.33695E+02 450543.2 5234354.5 392.6 192.44 361.48 12.64 8.84 YES NO  BEC_SV04 0 0.64372E+02 450653.8 5234624.5 394.6 170.31 343.15 35.85 6.10 YES NO  BEC_SV09 0 0.78000E-01 450631.3 5234411.0 396.2 13.72 699.82 20.21 0.24 YES NO  BEC_SV10 0 0.94000E-01 450683.1 5234583.0 395.4 8.23 699.82 8.80 0.64 YES NO  BEC_SV15 0 0.27000E-01 450581.8 5234460.0 394.4 17.98 294.26 0.00 0.15 YES NO  BEC_SV16 0 0.43000E-01 450296.8 5234813.5 396.2 46.33 294.26 0.00 0.15 YES NO  BEC_SV17 0 0.15000E-01 450303.2 5234810.0 396.2 46.33 294.26 0.00 0.15 YES NO  BEC_SV18 0 0.12000E-01 450298.0 5234808.0 396.2 46.33 294.26 0.00 0.15 YES NO  BEC_SV20 0 0.18000E-01 450620.7 5234623.5 394.4 17.22 294.26 0.00 1.23 YES NO  BEC_SV21 0 0.18000E-01 450617.9 5234627.0 394.4 17.22 294.26 0.00 1.23 YES NO  BEC_SV22 0 0.80000E-02 450555.3 5234413.5 394.3 9.14 847.04 10.49 0.20 YES NO  BEC_SV23 0 0.25200E+00 450736.8 5234139.0 397.5 6.40 294.26 46.04 1.42 YES NO 
APPENDIX B 

Dispersion Modeling Parameters 

Minnesota Power - Boswell Energy Center 

Permit Number: 06100004-004 

 *** THE SUMMARY OF MAXIMUM PERIOD ( 8784 HRS) RESULTS ***  ** CONC OF OTHER IN MICROGRAMS/M**3 ** GROUP ID AVERAGE CONC RECEPTOR (XR, YR, ZELEV, ZHILL, ZFLAG) OF TYPE GRI- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ALL 1ST HIGHEST VALUE IS 7.50431 AT ( 450543.22, 5234704.50, 391.86, 391.86, 0.00) DC  *** THE SUMMARY OF HIGHEST 24-HR RESULTS ***  ** CONC OF OTHER IN MICROGRAMS/M**3 **  DATE GROUP ID AVERAGE CONC (YYMMDDHH) RECEPTOR (XR, YR, ZELEV, ZHILL, ZFLAG) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ALL HIGH 1ST HIGH VALUE IS 61.66373 ON 89112024: AT ( 450687.31, 5233790.50, 394.96, 394.96,  HIGH 2ND HIGH VALUE IS 56.72338 ON 90011124: AT ( 450687.31, 5233790.50, 394.96, 394.96,  HIGH 3RD HIGH VALUE IS 52.64199c ON 86011224: AT ( 450687.31, 5233790.50, 394.96, 394.96,  HIGH 4TH HIGH VALUE IS 47.35564c ON 86011224: AT ( 450677.31, 5233790.50, 395.00, 396.24,  HIGH 5TH HIGH VALUE IS 34.63295 ON 90041624: AT ( 450687.31, 5233790.50, 394.96, 394.96,  HIGH 6TH HIGH VALUE IS 30.75789 ON 89092224: AT ( 450657.31, 5233790.50, 396.03, 396.03,  *** P12 Itr 2; INL-INL, MN Metdata 1990 *** **MODELOPTs: CONC DFAULT ELEV MULTYR  *** POINT SOURCE DATA ***  NUMBER EMISSION RATE BASE STACK STACK STACK STACK BLDG URBAN  SOURCE PART. (GRAMS/SEC) X Y ELEV. HEIGHT TEMP. EXIT VEL. DIAMETER EXISTS SOURCE  ID CATS. (METERS) (METERS) (METERS) (METERS) (DEG.K) (M/SEC) (METERS) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -  BEC_SV01 0 0.47250E+01 450572.1 5234322.5 394.8 76.20 394.26 10.57 2.90 YES NO  BEC_SV03 0 0.73980E+01 450543.2 5234354.5 392.6 192.44 305.37 4.25 8.84 YES NO  BEC_SV04 0 0.32186E+02 450653.8 5234624.5 394.6 170.31 330.37 17.92 6.10 YES NO 
APPENDIX B 

Dispersion Modeling Parameters 

Minnesota Power - Boswell Energy Center 

Permit Number: 06100004-004 

 BEC_SV15 0 0.27000E-01 450581.8 5234460.0 394.4 17.98 294.26 0.00 0.15 YES NO  BEC_SV16 0 0.43000E-01 450296.8 5234813.5 396.2 46.33 294.26 0.00 0.15 YES NO  BEC_SV17 0 0.15000E-01 450303.2 5234810.0 396.2 46.33 294.26 0.00 0.15 YES NO  BEC_SV18 0 0.12000E-01 450298.0 5234808.0 396.2 46.33 294.26 0.00 0.15 YES NO  BEC_SV20 0 0.18000E-01 450620.7 5234623.5 394.4 17.22 294.26 0.00 1.23 YES NO  BEC_SV21 0 0.18000E-01 450617.9 5234627.0 394.4 17.22 294.26 0.00 1.23 YES NO  BEC_SV23 0 0.25200E+00 450736.8 5234139.0 397.5 6.40 294.26 46.04 1.42 YES NO  *** THE SUMMARY OF MAXIMUM PERIOD ( 8784 HRS) RESULTS ***  ** CONC OF OTHER IN MICROGRAMS/M**3 ** GROUP ID AVERAGE CONC RECEPTOR (XR, YR, ZELEV, ZHILL, ZFLAG) OF TYPE GRI- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ALL 1ST HIGHEST VALUE IS 7.54244 AT ( 450543.22, 5234704.50, 391.86, 391.86, 0.00) DC  *** THE SUMMARY OF HIGHEST 24-HR RESULTS ***  ** CONC OF OTHER IN MICROGRAMS/M**3 **  DATE GROUP ID AVERAGE CONC (YYMMDDHH) RECEPTOR (XR, YR, ZELEV, ZHILL, ZFLAG) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ALL HIGH 1ST HIGH VALUE IS 62.38565 ON 89112024: AT ( 450687.31, 5233790.50, 394.96, 394.96,  HIGH 2ND HIGH VALUE IS 56.71721 ON 90011124: AT ( 450687.31, 5233790.50, 394.96, 394.96,  HIGH 3RD HIGH VALUE IS 54.43631c ON 86011224: AT ( 450687.31, 5233790.50, 394.96, 394.96,  HIGH 4TH HIGH VALUE IS 49.72771 ON 89050524: AT ( 450687.31, 5233790.50, 394.96, 394.96,  HIGH 5TH HIGH VALUE IS 34.65719 ON 90041624: AT ( 450687.31, 5233790.50, 394.96, 394.96,  HIGH 6TH HIGH VALUE IS 31.19517 ON 89092224: AT ( 450667.31, 5233790.50, 395.46, 395.46,  *** S01 Annual Itr 2; INL-INL, MN Metdata 1987 *** **MODELOPTs: CONC DFAULT ELEV  *** POINT SOURCE DATA *** 
APPENDIX B 

Dispersion Modeling Parameters 

Minnesota Power - Boswell Energy Center 

Permit Number: 06100004-004 

 NUMBER EMISSION RATE BASE STACK STACK STACK STACK BLDG URBAN  SOURCE PART. (GRAMS/SEC) X Y ELEV. HEIGHT TEMP. EXIT VEL. DIAMETER EXISTS SOURCE  ID CATS. (METERS) (METERS) (METERS) (METERS) (DEG.K) (M/SEC) (METERS) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -  BEC_SV03 0 0.79403E+03 450543.2 5234354.5 392.6 192.44 361.48 12.64 8.84 YES NO  BEC_SV04 0 0.21243E+03 450653.8 5234624.5 394.6 170.31 343.15 35.85 6.10 YES NO  BEC_SV09 0 0.70000E-02 450631.3 5234411.0 396.2 13.72 699.82 20.21 0.24 YES NO  BEC_SV10 0 0.94500E+00 450683.1 5234583.0 395.4 8.23 699.82 8.80 0.64 YES NO  BEC_SV22 0 0.20000E-02 450555.3 5234413.5 394.3 9.14 847.04 10.49 0.20 YES NO  *** THE SUMMARY OF MAXIMUM PERIOD ( 8760 HRS) RESULTS ***  ** CONC OF SO2 IN MICROGRAMS/M**3 ** GROUP ID AVERAGE CONC RECEPTOR (XR, YR, ZELEV, ZHILL, ZFLAG) OF TYPE GRI- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ALL 1ST HIGHEST VALUE IS 9.22156 AT ( 450572.66, 5234629.00, 392.04, 392.04, 0.00) DC  *** S01 Short-term Itr 2; INL-INL, MN Metdata 1989 *** **MODELOPTs: CONC DFAULT ELEV  *** POINT SOURCE DATA ***  NUMBER EMISSION RATE BASE STACK STACK STACK STACK BLDG URBAN  SOURCE PART. (GRAMS/SEC) X Y ELEV. HEIGHT TEMP. EXIT VEL. DIAMETER EXISTS SOURCE  ID CATS. (METERS) (METERS) (METERS) (METERS) (DEG.K) (M/SEC) (METERS) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -  BEC_SV03 0 0.24469E+04 450543.2 5234354.5 392.6 192.44 361.48 12.64 8.84 YES NO  BEC_SV04 0 0.77246E+03 450653.8 5234624.5 394.6 170.31 343.15 35.85 6.10 YES NO  BEC_SV09 0 0.12600E+00 450631.3 5234411.0 396.2 13.72 699.82 20.21 0.24 YES NO  BEC_SV10 0 0.94500E+00 450683.1 5234583.0 395.4 8.23 699.82 8.80 0.64 YES NO  BEC_SV22 0 0.35000E-01 450555.3 5234413.5 394.3 9.14 847.04 10.49 0.20 YES NO  *** THE SUMMARY OF HIGHEST 1-HR RESULTS *** 
APPENDIX B 

Dispersion Modeling Parameters 

Minnesota Power - Boswell Energy Center 

Permit Number: 06100004-004 

 ** CONC OF SO2 IN MICROGRAMS/M**3 **  DATE GROUP ID AVERAGE CONC (YYMMDDHH) RECEPTOR (XR, YR, ZELEV, ZHILL, ZFLAG) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ALL HIGH 1ST HIGH VALUE IS 796.42310 ON 89032314: AT ( 449175.12, 5238113.50, 392.89, 392.89,  HIGH 2ND HIGH VALUE IS 548.07581 ON 89032314: AT ( 449935.44, 5237801.50, 392.58, 392.58,  *** THE SUMMARY OF HIGHEST 3-HR RESULTS ***  ** CONC OF SO2 IN MICROGRAMS/M**3 **  DATE GROUP ID AVERAGE CONC (YYMMDDHH) RECEPTOR (XR, YR, ZELEV, ZHILL, ZFLAG) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ALL HIGH 1ST HIGH VALUE IS 456.37442 ON 89071812: AT ( 450334.84, 5233172.50, 390.14, 390.14,  HIGH 2ND HIGH VALUE IS 424.45447 ON 89071412: AT ( 450334.84, 5233172.50, 390.14, 390.14,  *** THE SUMMARY OF HIGHEST 24-HR RESULTS ***  ** CONC OF SO2 IN MICROGRAMS/M**3 **  DATE GROUP ID AVERAGE CONC (YYMMDDHH) RECEPTOR (XR, YR, ZELEV, ZHILL, ZFLAG) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ALL HIGH 1ST HIGH VALUE IS 179.11818c ON 87070824: AT ( 450300.12, 5232976.00, 390.40, 390.40,  HIGH 2ND HIGH VALUE IS 157.92535 ON 87071224: AT ( 450230.66, 5232582.00, 390.14, 390.14,  *** S02 Annual Itr 2; INL-INL, MN Metdata 1990 *** **MODELOPTs: CONC DFAULT ELEV  *** POINT SOURCE DATA ***  NUMBER EMISSION RATE BASE STACK STACK STACK STACK BLDG URBAN  SOURCE PART. (GRAMS/SEC) X Y ELEV. HEIGHT TEMP. EXIT VEL. DIAMETER EXISTS SOURCE  ID CATS. (METERS) (METERS) (METERS) (METERS) (DEG.K) (M/SEC) (METERS) 
APPENDIX B 

Dispersion Modeling Parameters 

Minnesota Power - Boswell Energy Center 

Permit Number: 06100004-004 

- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -  BEC_SV03 0 0.59552E+03 450543.2 5234354.5 392.6 192.44 355.37 9.48 8.84 YES NO  BEC_SV04 0 0.15932E+03 450653.8 5234624.5 394.6 170.31 338.71 26.89 6.10 YES NO  *** THE SUMMARY OF MAXIMUM PERIOD ( 8760 HRS) RESULTS ***  ** CONC OF SO2 IN MICROGRAMS/M**3 ** GROUP ID AVERAGE CONC RECEPTOR (XR, YR, ZELEV, ZHILL, ZFLAG) OF TYPE GRI- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ALL 1ST HIGHEST VALUE IS 3.70379 AT ( 452275.28, 5233354.50, 388.01, 388.01, 0.00) DC  *** S02 Short-term Itr 2; INL-INL, MN Metdata 1989 *** **MODELOPTs: CONC DFAULT ELEV  *** POINT SOURCE DATA ***  NUMBER EMISSION RATE BASE STACK STACK STACK STACK BLDG URBAN  SOURCE PART. (GRAMS/SEC) X Y ELEV. HEIGHT TEMP. EXIT VEL. DIAMETER EXISTS SOURCE  ID CATS. (METERS) (METERS) (METERS) (METERS) (DEG.K) (M/SEC) (METERS) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -  BEC_SV03 0 0.18352E+04 450543.2 5234354.5 392.6 192.44 355.37 9.48 8.84 YES NO  BEC_SV04 0 0.57935E+03 450653.8 5234624.5 394.6 170.31 338.71 26.89 6.10 YES NO  *** THE SUMMARY OF HIGHEST 1-HR RESULTS ***  ** CONC OF SO2 IN MICROGRAMS/M**3 **  DATE GROUP ID AVERAGE CONC (YYMMDDHH) RECEPTOR (XR, YR, ZELEV, ZHILL, ZFLAG) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ALL HIGH 1ST HIGH VALUE IS 725.31946 ON 89032314: AT ( 449346.16, 5237643.50, 392.58, 392.58,  HIGH 2ND HIGH VALUE IS 468.49081 ON 89032713: AT ( 450022.28, 5237309.00, 392.28, 392.28,  *** THE SUMMARY OF HIGHEST 3-HR RESULTS ***  ** CONC OF SO2 IN MICROGRAMS/M**3 ** 
APPENDIX B 

Dispersion Modeling Parameters 

Minnesota Power - Boswell Energy Center 

Permit Number: 06100004-004 

 DATE GROUP ID AVERAGE CONC (YYMMDDHH) RECEPTOR (XR, YR, ZELEV, ZHILL, ZFLAG) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ALL HIGH 1ST HIGH VALUE IS 420.11865 ON 89072012: AT ( 450751.59, 5233172.50, 388.01, 388.01,  HIGH 2ND HIGH VALUE IS 387.68100 ON 89071412: AT ( 450334.84, 5233172.50, 390.14, 390.14,  *** THE SUMMARY OF HIGHEST 24-HR RESULTS ***  ** CONC OF SO2 IN MICROGRAMS/M**3 **  DATE GROUP ID AVERAGE CONC (YYMMDDHH) RECEPTOR (XR, YR, ZELEV, ZHILL, ZFLAG) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ALL HIGH 1ST HIGH VALUE IS 163.01523c ON 87070724: AT ( 450543.22, 5232954.50, 389.84, 389.84,  HIGH 2ND HIGH VALUE IS 139.78828c ON 87082724: AT ( 450334.84, 5233172.50, 390.14, 390.14,  *** S04 Annual Itr 2; INL-INL, MN Metdata 1987 *** **MODELOPTs: CONC DFAULT ELEV  *** POINT SOURCE DATA ***  NUMBER EMISSION RATE BASE STACK STACK STACK STACK BLDG URBAN  SOURCE PART. (GRAMS/SEC) X Y ELEV. HEIGHT TEMP. EXIT VEL. DIAMETER EXISTS SOURCE  ID CATS. (METERS) (METERS) (METERS) (METERS) (DEG.K) (M/SEC) (METERS) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -  BEC_SV03 0 0.38045E+02 450543.2 5234354.5 392.6 192.44 329.26 8.50 8.84 YES NO  BEC_SV04 0 0.21243E+03 450653.8 5234624.5 394.6 170.31 343.15 35.85 6.10 YES NO  BEC_SV09 0 0.70000E-02 450631.3 5234411.0 396.2 13.72 699.82 20.21 0.24 YES NO  BEC_SV10 0 0.94500E+00 450683.1 5234583.0 395.4 8.23 699.82 8.80 0.64 YES NO  BEC_SV22 0 0.20000E-02 450555.3 5234413.5 394.3 9.14 847.04 10.49 0.20 YES NO  *** THE SUMMARY OF MAXIMUM PERIOD ( 8760 HRS) RESULTS ***  ** CONC OF SO2 IN MICROGRAMS/M**3 ** 
APPENDIX B 

Dispersion Modeling Parameters 

Minnesota Power - Boswell Energy Center 

Permit Number: 06100004-004 

GROUP ID AVERAGE CONC RECEPTOR (XR, YR, ZELEV, ZHILL, ZFLAG) OF TYPE GRI- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ALL 1ST HIGHEST VALUE IS 9.22035 AT ( 450572.66, 5234629.00, 392.04, 392.04, 0.00) DC  *** S04 Short-term Itr 2; INL-INL, MN Metdata 1987 *** **MODELOPTs: CONC DFAULT ELEV  *** POINT SOURCE DATA ***  NUMBER EMISSION RATE BASE STACK STACK STACK STACK BLDG URBAN  SOURCE PART. (GRAMS/SEC) X Y ELEV. HEIGHT TEMP. EXIT VEL. DIAMETER EXISTS SOURCE  ID CATS. (METERS) (METERS) (METERS) (METERS) (DEG.K) (M/SEC) (METERS) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -  BEC_SV03 0 0.12555E+04 450543.2 5234354.5 392.6 192.44 329.26 8.50 8.84 YES NO  BEC_SV04 0 0.77246E+03 450653.8 5234624.5 394.6 170.31 343.15 35.85 6.10 YES NO  BEC_SV09 0 0.12600E+00 450631.3 5234411.0 396.2 13.72 699.82 20.21 0.24 YES NO  BEC_SV10 0 0.94500E+00 450683.1 5234583.0 395.4 8.23 699.82 8.80 0.64 YES NO  BEC_SV22 0 0.35000E-01 450555.3 5234413.5 394.3 9.14 847.04 10.49 0.20 YES NO  *** THE SUMMARY OF HIGHEST 1-HR RESULTS ***  ** CONC OF SO2 IN MICROGRAMS/M**3 **  DATE GROUP ID AVERAGE CONC (YYMMDDHH) RECEPTOR (XR, YR, ZELEV, ZHILL, ZFLAG) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ALL HIGH 1ST HIGH VALUE IS 688.04608 ON 87112214: AT ( 450543.22, 5237354.50, 392.88, 392.88,  HIGH 2ND HIGH VALUE IS 427.86185 ON 87072815: AT ( 449943.22, 5233315.50, 388.01, 388.01,  *** THE SUMMARY OF HIGHEST 3-HR RESULTS ***  ** CONC OF SO2 IN MICROGRAMS/M**3 **  DATE GROUP ID AVERAGE CONC (YYMMDDHH) RECEPTOR (XR, YR, ZELEV, ZHILL, ZFLAG) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 
APPENDIX B 

Dispersion Modeling Parameters 

Minnesota Power - Boswell Energy Center 

Permit Number: 06100004-004 

ALL HIGH 1ST HIGH VALUE IS 398.49915 ON 89072012: AT ( 450716.88, 5233369.50, 388.01, 388.01,  HIGH 2ND HIGH VALUE IS 363.01028 ON 89071412: AT ( 450369.56, 5233369.50, 388.01, 388.01,  *** THE SUMMARY OF HIGHEST 24-HR RESULTS ***  ** CONC OF SO2 IN MICROGRAMS/M**3 **  DATE GROUP ID AVERAGE CONC (YYMMDDHH) RECEPTOR (XR, YR, ZELEV, ZHILL, ZFLAG) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ALL HIGH 1ST HIGH VALUE IS 155.74730c ON 87070724: AT ( 450543.22, 5232954.50, 389.84, 389.84,  HIGH 2ND HIGH VALUE IS 132.83893c ON 87082724: AT ( 450334.84, 5233172.50, 390.14, 390.14, 

*** AERMOD - VERSION 07026 *** *** 0959-20 MN Power - Boswell Energy Center ***  *** CO AERMOD Modeling; INL-INL, MN Metdata 1986 *** **MODELOPTs: CONC DFAULT ELEV  *** POINT SOURCE DATA ***  NUMBER EMISSION RATE BASE STACK STACK STACK STACK BLDG URBAN C SOURCE PART. (GRAMS/SEC) X Y ELEV. HEIGHT TEMP. EXIT VEL. DIAMETER EXISTS SOURCE H ID CATS. (METERS) (METERS) (METERS) (METERS) (DEG.K) (M/SEC) (METERS) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -  BEC_SV03 0 0.63408E+03 450543.2 5234354.5 392.6 192.44 329.26 8.50 8.84 YES NO  BEC_SV22 0 0.25000E+00 450519.0 5234415.0 394.3 9.14 772.59 22.92 0.25 YES NO 
APPENDIX C 

NOx Compliance Plan 

Minnesota Power - Boswell Energy Center 

Permit Number: 06100004-004 

Phase II NOx Compliance Plan 

For more information, see instructions and refer to 40 CFR 76.9 

This submission is: New (Renewal) Revised 

Step 1 

Indicate plant name, 

State, and ORIS code 

from NADB, if 

applicable 

Clay Boswell 

Plant Name 

MN 

State 

1893 

ORIS Code 

Step 2 Identify each affected Group 1 and Group 2 boiler using the boiler ID# from NADB, if 

applicable. Indicate boiler type: “CB” for cell burner, “CY” for cyclone, “DBW” for dry botton 

wall-fired, “T” for tangetially fired, “V” for vertically fired, and “WB” for wet bottom. Indicate the 

compliance option selected for each unit 

ID# 1 ID# 2 ID# 3 ID# 4 ID# ID# 

DBW 

Type 

DBW 

Type 

T 

Type 

T 

Type Type Type 

(a) Standard annual 

average 

emission limitation of 0.50 

lb/mmBtu (for Phase I dry 

bottom wall-fired boilers)

 

(b) Standard annual 

average 

emission limitation of 0.45 

lb/mmBtu (for Phase I 

tangentially fired boilers)

 

(c) EPA-approved early 

election plan under 40 

CFR 76.8 through 

12/31/07 (also indicate 

above emission limit 

specified in plan)

 

(d) Standard annual 

average 

emission limitation of 0.46 

lb/mmBtu (for Phase II dry 

 

X 
APPENDIX C 

NOx Compliance Plan 

Minnesota Power - Boswell Energy Center 

Permit Number: 06100004-004 

bottom wall-fired boilers)

(e) Standard annual 

average 

emission limitation of 0.40 

lb/mmBtu (for Phase II 

tangentially fired boilers)

 

(f) Standard annual 

average 

emission limitation of 0.68 

lb/mmBtu (for cell burner 

boilers)

 

(g) Standard annual 

average 

emission limitation of 0.86 

lb/mmBtu (for cyclone 

boilers)

 

(h) Standard annual 

average 

emission limitation of 0.80 

lb/mmBtu (for vertically 

fired boilers)

 

(i) Standard annual 

average 

emission limitation of 0.84 

lb/mmBtu (for wet bottom 

boilers)

 

(j) NOx Averaging Plan 

(include NOx Averaging 

form)

X X X X 

(k) Common stack 

pursuant 

to 40 CFR 75.17(a)(2)(i)(A) 

(check the standard 

emission 

limitation box above for 

most stringent limitation 

applicable to any unit 

utilizing stack

 

(l) Common stack 

pursuant to 40 CFR 

75.17(a)(2)(i)(B) with NOx 

Averaging (check the NOx 

Averaging Plan box and 

include NOx Averaging 

form)

X X 

(m) EPA-approved 

common 

stack apportionment 

method 

pursuant to 40 CFR 75.17 

(a)(2)(i)(C), (a)(2)(iii)(B), or 

 
APPENDIX C 

NOx Compliance Plan 

Minnesota Power - Boswell Energy Center 

Permit Number: 06100004-004 

(b)(2)

(n) AEL (include Phase II 

AEL Demonstration 

Period, Final AEL Petition, 

or AEL Renewal form as 

appropriate)

 

(o) Petition for AEL 

demonstration period or 

final AEL under review by 

U.S. EPA or 

demonstration period 

ongoing

 

(p) Repowering extension 

plan approved or under 

review

 

Standard Requirements

General. This source is subject to the standard requirements in 40 CFR 72.9 (consistent with 40 CFR 76.8(e)(1)(i)). 

These requirements are listed in this source's Acid Rain Permit. 

Special Provisions for Early Election Units 

Nitrogen Oxides. A unit that is governed by an approved early election plan shall be subject to an emissions 

limitation for NO x as provided under 40 CFR 76.8(a)(2) except as provided under 40 CFR 76.8(e)(3)(iii). 

Liability. The owners and operators of a unit governed by an approved early election plan shall be liable for any 

violation of the plan or 40 CFR 76.8 at that unit. The owners and operators shall be liable, beginning January 1, 

2000, for fulfilling the obligations specified in 40 CFR Part 77. 

Termination. An approved early election plan shall be in effect only until the earlier of January 1, 2008 or January 

1 of the calendar year for which a termination of the plan takes effect. If the designated representative of the unit 

under an approved early election plan fails to demonstrate compliance with the applicable emissions limitation 

under 40 CFR 76.5 for any year during the period beginning January 1 of the first year the early election takes 

effect and ending December 31, 2007, the permitting authority will terminate the plan. The termination will take 

effect beginning January 1 of the year after the year for which there is a failure to demonstrate compliance, and the 

designated representative may not submit a new early election plan. The designated representative of the unit 

under an approved early election plan may terminate the plan any year prior to 2008 but may not submit a new 

early election plan. In order to terminate the plan, the designated representative must submit a notice under 40 

CFR 72.40(d) by January 1 of the year for which the termination is to take effect. If an early election plan is 

terminated any year prior to 2000, the unit shall meet, beginning January 1, 2000, the applicable emissions limitation for 

NO x for Phase II units with Group 1 boilers under 40 CFR 76.7. If an early election plan is terminated on or after 2000, 

the unit shall meet, beginning on the effective date of the termination, the applicable emissions limitation for NO x for Phase 

II units with Group 1 boilers under 40 CFR 76.7. 
APPENDIX C 

NOx Compliance Plan 

Minnesota Power - Boswell Energy Center 

Permit Number: 06100004-004 

Phase II NOx Averaging Plan 

For more information, see instructions and refer to 40 CFR 76.11 

This submission is: New Revised 

Step 1 

Identify the units participating in this averaging plan by plant name, State, and boiler ID# from 

NADB. In column (a), fill in each unit’s applicable emission limitation from 40 CFR 76.5, 76.6, or 

76.7. In column (b), assign an alternative contemporaneous annual emissions limitation in 

lb/mmBtu to each unit. In column (c), assign an annual heat input limitation in mmBtu to each 

unit. Continue to page 3 if necessary. 

 (b) (c) 

 Alt. Annual 

 (a) Contemp. Heat 

 Emission Emission Input 

Plant Name State ID# Limitation Limitation Limit 

Clay Boswell MN 1 0.46 0.45 3,500,000 

Clay Boswell MN 2 0.46 0.45 3,500,000 

Clay Boswell MN 3 0.40 0.39 19,000,000 

Clay Boswell MN 4 0.40 0.35 33,000,000 

Syl Laskin MN 1 0.40 0.50 4,600,000 

Syl Laskin MN 2 0.40 0.50 4,600,000 

Taconite Harbor MN 1 0.40 0.45 5,600,000 

Taconite Harbor MN 2 0.40 0.45 5,600,000 

Taconite Harbor MN 3 0.40 0.45 5,600,000 

Step 2 

Use the formula to enter the Btu-weighted annual emission rate averaged over the units if they are 

operated in accordance with the proposed averaging plan and the Btu-weighted annual averge 

emission rate for the same units if they are operated in compliance with 40 CFR 76.5, 76.6, or 76.7. 

The former must be less than or equal to the latter. 

Btu-weighted annual emission rate Btu-weighted annual average 

averaged over the units if they are emission rate for same units 

operated in accordance with the operated in compliance with 

proposed averaging plan 40 CFR 76.5, 76.6, or 76.7 

X 
APPENDIX C 

NOx Compliance Plan 

Minnesota Power - Boswell Energy Center 

Permit Number: 06100004-004 

n n 

Σ (RLi x HIi) Σ [Rli x HIi] 

i=l i=l 

________________ < __________________ 

 n n 

 Σ HIi Σ HIi 

 i=l i=l 

Where, 

RLi = Alternative contemporaneous annual emission limitation 

 unit i, in lb/mmBtu, as specified in column (b) of Step 1: 

Rli = Applicable emission limitation for unit i, in lb/mmBtu, as 

 specified in column (a) of Step 1: 

HIi = Annual heat input for unit i, in mmBtu, as specified in 

 column (c) of Step 1: 

n = Number of units in the averaging plan 

This plan is effective for calendar year _2008_ through calendar year _2011_ 

unless notification to terminate the plan is given. 

Treat this plan as identical plans, each effective for one calendar year for the 

following calendar 

years ______, ______, ______, ______, and ______ unless notification to terminate one or more of 

these plans is given.

Special Provisions 

 

 0.40 

 

 0.40 

X 

 
APPENDIX C 

NOx Compliance Plan 

Minnesota Power - Boswell Energy Center 

Permit Number: 06100004-004 

Emission Limitations

Each affected unit in an approved averaging plan is in compliance with the Acid Rain emission limitation for NOx 

under the plan only if the following requirements are met: 

 (i) For each unit, the unit's actual annual average emission rate for the calendar year, in lb/mmBtu, is less 

 than or equal to its alternative contemporaneous annual emission limitation in the averaging plan, and 

 (a) For each unit with an alternative contemporaneous emission limitation less stringent than the 

 applicable emission limitation in 40 CFR 76.5, 76.6, or 76.7, the actual annual heat input for the 

 calendar year does not exceed the annual heat input limit in the averaging plan, 

 (b) For each unit with an alternative contemporaneous emission limitation more stringent than the 

 applicable emission limitation in 40 CFR 76.5, 76.6, or 76.7, the actual annual heat input for the 

 calendar year is not less than the annual heat input limit in the averaging plan, or 

 (ii) If one or more of the units does not meet the requirements of (i), the designated representative shall 

 demonstrate, in accordance with 40 CFR 76.11(d)(1)(ii)(A) and (B), that the actual Btu-weighted annual 

 average emission rate for the units in the plan is less than or equal to the Btu-weighted annual average rate 

 for the same units had they each been operated, during the same period of time, in compliance with the 

 applicable emission limitations in 40 CFR 76.5, 76.6, or 76.7. 

 (iii) If there is a successful group showing of compliance under 40 CFR 76.11(d)(1)(ii)(A) and (B) for a 

 calendar year, then all units in the averaging plan shall be deemed to be in compliance for that year with 

 their alternative contemporaneous emission limitations and annual heat input limits under (i). 

Liability

The owners and operators of a unit governed by an approved averaging plan shall be liable for any violation of the 

plan or this section at that unit or any other unit in the plan, including liability for fulfilling the obligations specified in 

part 77 of this chapter and sections 113 and 411 of the Act. 

Termination

The designated representative may submit a notification to terminate an approved averaging plan, in 

accordance with 40 CFR 72.40(d), no later than October 1 of the calendar year for which the plan is 

to be terminated. 
APPENDIX C 

NOx Compliance Plan 

Minnesota Power - Boswell Energy Center 

Permit Number: 06100004-004 

Phase II Permit Application 

For more information, see instructions and refer to 40 CFR 72.30 and 72.31 

This submission is New Revised 

Clay Boswell

Plant Name

MN 

State

1893 

ORIS Code

 Compliance 

 Plan 

a 

Boiler ID# 

b 

Unit Will Hold 

Allowances in 

Accordance with 

40 CFR 

72.9(c)(1) 

c 

Repowering Plan 

d 

New Units 

Commence 

Operation Date 

e 

New Units 

Monitor 

Certification 

Deadline 

1 Yes no 

2 Yes no 

3 Yes no 

4 Yes no 

 Yes 

 Yes 

 Yes 

 Yes 

 Yes 

 Yes 

 Yes 

Standard Requirements 

Permit Requirements.

X 
APPENDIX C 

NOx Compliance Plan 

Minnesota Power - Boswell Energy Center 

Permit Number: 06100004-004 

(1) The designated representative of each affected source and each affected unit at the source shall: 

 (i) Submit a complete Acid Rain permit application (including a compliance plan) under 40 CFR part 72 in accordance 

 with the deadlines specified in 40 CFR 72.30; and 

 (ii) Submit in a timely manner any supplemental information that the permitting authority determines is necessary in order 

 to review an Acid Rain permit application and issue or deny an Acid Rain permit; 

(2) The owners and operators of each affected source and each affected unit at the source shall: 

 (i) Operate the unit in compliance with a complete Acid Rain permit application or a superseding Acid Rain permit issued 

 by the permitting authority; and 

 (ii) Have an Acid Rain Permit. 

Monitoring Requirements.

(1) The owners and operators and, to the extent applicable, designated representative of each affected source and each affected

unit at the source shall comply with the monitoring requirements as provided in 40 CFR parts 74, 75, 

and 76. 

(2) The emissions measurements recorded and reported in accordance with 40 CFR part 75 shall be used to determine 

compliance by the unit with the Acid Rain emissions limitations and emissions reduction requirements for sulfur dioxide and 

nitrogen oxides under the Acid Rain Program. 

(3) The requirements of 40 CFR parts 74 and 75 shall not affect the responsibility of the owners and operators to monitor 

emissions of other pollutants or other emissions characteristics at the unit under other applicable requirements of the Act and other 

provisions of the operating permit for the source. 

Sulfur Dioxide Requirements.

(1) The owners and operators of each source and each affected unit at the source shall: 

 (i) Hold allowances, as of the allowance transfer deadline, in the unit's compliance subaccount (after deductions under 40 

 CFR 73.34(c)) not less than the total annual emissions of sulfur dioxide for the previous calendar year from the unit; and 

 (ii) Comply with the applicable Acid Rain emissions limitations for sulfur dioxide. 

(2) Each ton of sulfur dioxide emitted in excess of the Acid Rain emissions limitations for sulfur dioxide shall constitute a separate 

violation of the Act. 

(3) An affected unit shall be subject to the requirements under paragraph (1) of the sulfur dioxide requirements 

as follows: 

 (i) Starting January 1, 2000, an affected unit under 40 CFR 72.6(a)(2); or 

 (ii) Starting on the later of January 1, 2000 or the deadline for monitor certification under 40 CFR part 75, an affected unit

 under 40 CFR 72.6(a)(3). 

(4) Allowances shall be held in, deducted from, or transferred among Allowance Tracking System accounts in accordance with 

the Acid Rain Program. 

(5) An allowance shall not be deducted in order to comply with the requirements under paragraph (1)(i) of the sulfur dioxide 

requirements prior to the calendar year for which the allowance was allocated. 

(6) An allowance allocated by the Administrator under the Acid Rain Program is a limited authorization to emit sulfur dioxide in 

accordance with the Acid Rain Program. No provision of the Acid Rain Program, the Acid Rain permit application, the Acid Rain 

permit, or the written exemption under 40 CFR 72.7 and 72.8 and no provision of law shall be construed to limit the authority of 

the United States to terminate or limit such authorization. 

(7) An allowance allocated by the Administrator under the Acid Rain Program does not constitute a property 

right. 

Nitrogen Oxides Requirements. The owners and operators of the source and each affected unit at the source shall comply with 

the applicable Acid Rain emissions limitation for nitrogen oxides. 

Excess Emissions Requirements.

(1) The designated representative of an affected unit that has excess emissions in any calendar year shall submit a proposed 

offset plan, as required under 40 CFR part 77. 

(2) The owners and operators of an affected unit that has excess emissions in any calendar year shall: 

 (i) Pay without demand the penalty required, and pay upon demand the interest on that penalty, as required by 40 CFR 

 part 77; and 

 (ii) Comply with the terms of an approved offset plan, as required by 40 CFR part 77. 

Recordkeeping and Reporting Requirements.

(1) Unless otherwise provided, the owners and operators of the source and each affected unit at the source shall keep on site 

at the source each of the following documents for a period of 5 years from the date the document is created. This period may be

extended for cause, at any time prior to the end of 5 years, in writing by the Administrator or permitting authority: 

 (i) The certificate of representation for the designated representative for the source and each affected unit at the source 

 and all documents that demonstrate the truth of the statements in the certificate of representation, in accordance with 40 

 CFR 72.24; provided that the certificate and documents shall be retained on site at the source beyond such 5-year period 
APPENDIX C 

NOx Compliance Plan 

Minnesota Power - Boswell Energy Center 

Permit Number: 06100004-004 

 until such documents are superseded because of the submission of a new certificate of representation changing the 

 designated representative; 

 (ii) All emissions monitoring information, in accordance with 40 CFR part 75; 

 (iii) Copies of all reports, compliance certifications, and other submissions and all records made or required under the 

 Acid Rain Program; and, 

 (iv) Copies of all documents used to complete an Acid Rain permit application and any other submission under the Acid 

 Rain Program or to demonstrate compliance with the requirements of the Acid Rain Program. 

(2) The designated representative of an affected source and each affected unit at the source shall submit the reports and 

compliance certifications required under the Acid Rain Program, including those under 40 CFR part 72 subpart I and 40 CFR part 

75.

Liability.

(1) Any person who knowingly violates any requirement or prohibition of the Acid Rain Program, a complete Acid Rain permit 

application, an Acid Rain permit, or a written exemption under 40 CFR 72.7 or 72.8, including any requirement for the payment 

of any penalty owed to the United States, shall be subject to enforcement pursuant to section 113(c) 

of the Act. 

(2) Any person who knowingly makes a false, material statement in any record, submission, or report under the Acid Rain 

Program shall be subject to criminal enforcement pursuant to section 113(c) of the Act and 18 U.S.C. 1001. 

(3) No permit revision shall excuse any violation of the requirements of the Acid Rain Program that occurs prior to the date that 

the revision takes effect. 

(4) Each affected source and each affected unit shall meet the requirements of the Acid Rain Program. 

(5) Any provision of the Acid Rain Program that applies to an affected source (including a provision applicable to the designated 

representative of an affected source) shall also apply to the owners and operators of such source and of the affected units at the 

source. 

(6) Any provision of the Acid Rain Program that applies to an affected unit (including a provision applicable to the designated

representative of an affected unit) shall also apply to the owners and operators of such unit. Except as provided under 40 CFR 

72.44 (Phase II repowering extension plans) and 40 CFR 76.11 (NO x averaging plans), and except with regard to the requirements 

applicable to units with a common stack under 40 CFR part 75 (including 40 CFR 75.16, 75.17, and 75.18), the owners and 

operators and the designated representative of one affected unit shall not be liable for any violation by any other affected unit of 

which they are not owners or operators or the designated representative and that is located at a source of which they are not 

owners or operators or the designated representative. 

(7) Each violation of a provision of 40 CFR parts 72, 73, 74, 75, 76, 77, and 78 by an affected source or affected unit, or by an 

owner or operator or designated representative of such source or unit, shall be a separate violation of the 

Act. 

Effect on Other Authorities. No provision of the Acid Rain Program, an Acid Rain permit application, an Acid Rain permit, or a 

written exemption under 40 CFR 72.7 or 72.8 shall be construed as: 

(1) Except as expressly provided in title IV of the Act, exempting or excluding the owners and operators and, to the extent 

applicable, the designated representative of an affected source or affected unit from compliance with any other provision of the 

Act, including the provisions of title I of the Act relating to applicable National Ambient Air Quality Standards or State 

Implementation Plans; 

(2) Limiting the number of allowances a unit can hold; provided, that the number of allowances held by the unit shall not affect 

the source's obligation to comply with any other provisions of the Act; 

(3) Requiring a change of any kind in any State law regulating electric utility rates and charges, affecting any State law regarding 

such State regulation, or limiting such State regulation, including any prudence review requirements under such 

State law; 

(4) Modifying the Federal Power Act or affecting the authority of the Federal Energy Regulatory Commission under the Federal 

Power Act; or, 

(5) Interfering with or impairing any program for competitive bidding for power supply in a State in which such program is 

established. 

 

Technical Support Document, Permit Action Number: 06100004 - 004

Page 1 of 21 

Date: 9/18/2009 

TECHNICAL SUPPORT DOCUMENT

For 

AIR EMISSION PERMIT NO. 06100004-004

This technical support document is intended for all parties interested in the permit and to meet 

the requirements that have been set forth by the federal and state regulations (40 CFR § 

70.7(a)(5) and Minn. R. 7007.0850, subp. 1). The purpose of this document is to provide the 

legal and factual justification for each applicable requirement or policy decision considered in 

the preliminary determination to issue the permit. 

1. General Information 

1.1. Applicant and Stationary Source Location:

Applicant/Address Stationary Source/Address 

(SIC Code: 4911) 

Minnesota Power Division of Allete, Inc. 

30 West Superior Street 

Duluth MN, 55802 

Boswell Energy Center

1210 3rd St NW 

Cohasset 

Itasca County 

Contact: Misty Hanson 

Phone: 218-328-5036 

1.2. Description of the Facility

The Boswell Energy Center (facility) is a coal-fired electric utility steam generating plant. 

Emission units at the facility include four power boilers, emergency engine generators, and fuel, 

additive and ash handling equipment. The main fuel for all boilers is sub bituminous coal. They 

may also burn distillate oil, limited amounts of boiler cleaning agents, used oil, oily coal, oily 

paper-based floor dry, wastewater treatment plant sludge, and oily materials (earth substrate with 

petroleum product). Emissions are controlled by baghouses, over fire air, selective NonCatalytic Reduction on Boilers 1 and 2. Low Nitrogen Oxide (NOx) burners, over fire air, 

selective catalytic reduction, baghouse filter a wet scrubber on Boiler 3, and a wet venturi 

scrubber / electrostatic precipitator, and sulfur dioxide spray towers on Boiler 4. 

1.3 Description of the Activities Allowed by this Permit Action

There are three separate major amendments rolled into this permit action. 

An application for a major amendment was submitted September 5, 2008. This application was 

submitted to revise the size of an emergency generator (EU 023) from 100 kW to 300 kW. This 

is known as the Generator Project within this TSD. This emergency generator unit (EGU) is part 

of the retrofitting project for EU003, permit No. 06100004-003 issued March 28, 2007. The 

EGU is to provide power for safe shutdown of pollution control equipment during power 
Technical Support Document, Permit Action Number: 06100004 - 004

Page 2 of 21 

Date: 9/18/2009 

outages. The original generator has not yet been installed. The original project was subject to 

Prevention of Significant Deterioration (PSD) for Carbon Monoxide (CO). Because of the 

increase in CO emission due to the larger EGU the facility has submitted a revised PSD analysis 

for CO. This includes updated Best Available Control Technology (BACT) and CO air 

dispersion modeling. (DQ 2218) 

An application for a major amendment was submitted September 15, 2008. This application is 

for installation of natural gas fired igniters/heat guns on all boilers; EU001, EU002, EU003, and 

EU004. All boilers currently have a set of oil-fired igniter/heat guns. The existing oil and new 

gas fired igniters/guns will not be fired simultaneously. Either oil or gas will be used at any 

given time on a per igniter or gun basis. The installation will include electrical switches and 

signals to ensure that it is not possible to fire both the oil fired and gas fired igniter/guns. A PSD 

analysis was conducted for CO and Volatile Organic Compounds (VOC). A facility wide natural 

gas usage limit will be used to avoid a significant increase in CO. (DQ 2232)

An application for a major amendment was submitted December 3, 2008. This application is for 

the installation of new Continuous Emissions Monitors Systems (CEMS). This would allow the 

facility to separately monitor the NOx, SOx, CO2, Opacity, and Air Flow for EU001, EU002, 

and EU003. This change does not involve any emissions increases or change to emission permit 

limits. (DQ 2342) 

An application for an administrative amendment was received by the MPCA. This amendment 

was submitted to correct allowable fuel for emergency generator 1 (EU007). This amendment 

does not authorize any changes to the facility. (Administrative amendment, DQ 1601) 

This permit amends the maximum achievable operating rates for boilers 3 and 4 (EU003, 

EU004). These updates stem from recent stack tests. 

This permit action also incorporates multiply Reopenings initiated by the MPCA. These are the 

incorporated Reopenings; Certified MR 040 to replace MR 005 for monitoring opacity for 

EU004, Certified MR 041 to replace MR 023 for monitoring air flow for EU004, March 21, 

2008 letter from Jeff Smith to Minnesota Power.

This permit also incorporates the requirements that stem from Title V modeling that was done by 

the permittee. 

This permit also incorporates a propane fired slag shock system. This system qualifies as an 

insignificant modification due to emissions. The system will be installed to target tougher-toremove slag deposits by using the percussion of a small controlled explosion to shock the 

deposits off of the boiler. Since the system will operate within the boiler propane has to be 

added to the allowable fuels list for all boilers at the facility. 

1.4. Facility Emissions:
Technical Support Document, Permit Action Number: 06100004 - 004

Page 3 of 21 

Date: 9/18/2009 

Table 1.1 Title I Emissions Increase Summary: NOx Reduction Project, Future-Projected Actual vs. Past 

Actual

Future-Projected 

Actual Emissions Past Actual 

Emissions 

Excludable 

Emissions 

(tons/yr) 

Projected 

Emissions 

Increase 

PSD 

Threshold 

Units 1 

& 2 

Paved 

Road 

Fugitives 

(Units 1 

& 2) 

Units 1 

& 2 

Paved 

Road 

Fugitives

(Units 1 & 

2) 

Baseline 

Years Increase 

prior to 

excludable 

 

Pollutant 

(tpy) (tpy) (tpy) (tpy) (tpy) (tpy) (tpy) (tpy) 

PM 66.0 2.9E-01 52.6 NA 2005-

2006 13.7 13.1 0.6 25 

PM10 60.7 5.7E-02 48.4 NA 2005-

2006 12.4 12.0 0.4 15 

PM2.5 35.1 8.6E-03 27.9 NA 2005-

2006 7.2 6.9 0.3 15 

SO2 7,372.7 --- 5,126.8 --- 2005-

2006 2,245.9 2,245.9 0.0 40 

NOx 1,116.9 --- 2,383.9 --- 2005-

2006 -1,267.0 1,393.6 -2,660.6 40 

CO 182.5 --- 144.3 --- 2005-

2006 38.2 38.2 0.0 100 

VOC 21.9 --- 17.3 --- 2005-

2006 4.6 4.6 0.0 40 

Lead 0.153 --- 0.12 --- 2005-

2006 3.2E-02 0.0 0.00 0.6 

H2SO4 169.3 --- 117.8 --- 2005-

2006 51.6 51.6 0.0 7.0 

Fluorides 54.8 --- 43.2 --- 2005-

2006 11.5 11.5 0.0 3.0 
Technical Support Document, Permit Action Number: 06100004 - 004

Page 4 of 21 

Date: 9/18/2009 

Table 1.2 Title I Emissions Increase Summary: Igniter/warm-up Guns Project, Future-Projected Actual vs. 

Past Actual 

Table 1.3 Non-Title I Emissions Increase Summary: Igniter/warm-up Guns Project, Future Potential vs. Past 

Potential

Future 

Potential 

Past 

Potential 

Projected 

Emissions 

Increase 

EAW 

Threshol

d AERA Pollutant 

(tpy) (tpy) (tpy) (tpy) (tpy) 

PM 5.12 5.12 0 250 100 

PM10 3.56 3.56 0 250 100 

PM2.5 2.39 2.39 0 250 100 

NOX 982.5 982.5 0 250 100 

So2 703.9 703.9 0 250 100 

CO 319.5 224.29 95.21 250 100 

VOC 20.9 8.98 11.92 250 100 

Lead 0.0088 0.0088 0 250 100 

Table 1.4 Total Facility Potential to Emit Summary 

 PM 

tpy 

PM10

tpy 

SO2

tpy 

NOx

tpy 

CO 

tpy 

VOC 

tpy 

Single 

HAP 

tpy 

All 

HAPs 

tpy 

Total Facility 

Limited Potential 

Emissions pre 

modification 

3831 2545 61501 24090 3431 180 3582 4066 
Technical Support Document, Permit Action Number: 06100004 - 004

Page 5 of 21 

Date: 9/18/2009 

Total Facility 

Limited Potential 

Emissions post 

modification 

3831 2545 61501 24090 3432 180 3582 4066 

Total Facility Actual 

Emissions (2007) 2,869 3,354 21,580 14,430 3,075 95.3 

HAPs not 

reported in 

emission 

inventory 

Table 1.5 Facility Classifications 

Classification Major/Affected 

Source 

Synthetic Minor Minor 

PSD X 

Part 70 Permit Program X 

Part 63 NESHAP X 

2. Regulatory and/or Statutory Basis

New Source Review

The facility is an existing major source under New Source Review (NSR) regulations. 

The igniter/gun project does not result in a significant increase in PSD regulated pollutants. An 

Actual to Projected Actual PSD analysis was conducted for all pollutants. Due to type of fuels 

involved there is an increase in emissions rate for only CO and Volatile Organic Compounds 

(VOC). Refer to Technical Information section for more details. 

The Emergency Generator does not result in a significant increase in PSD regulated pollutants. 

The original project was subject to Prevention of Significant Deterioration (PSD) for Carbon 

Monoxide (CO). Because of the increase in CO emission due to the larger EGU the facility has 

submitted a revised PSD analysis for CO. This includes updated Best Available Control 

Technology (BACT) and CO air dispersion modeling. Modeling was renewed by MPCA 

modeling staff. There were no problems with the modeling. Refer to Technical Information 

section for more details. 

The NOx reduction project does not result in a significant increase in PSD regulated pollutants. 

An Actual to Projected Actual PSD analysis was conducted for all pollutants. The project added 

an Over-Fire-Air system and a Selective Non-Catalytic Reduction system to reduce NOx 

emissions. The only criteria pollutants that have a potential to increase are PM, PM10, and PM2.5. 

This permit includes stack tests for PM and PM10 to confirm that there was not a significant 

increase in these pollutants. A PM2.5 stack test was not included because there is no prior stack 

test to compare the results to. Refer to Technical Information section for more details. 
Technical Support Document, Permit Action Number: 06100004 - 004

Page 6 of 21 

Date: 9/18/2009 

Part 70 Permit Program

The facility is a major source under the Part 70 permit program. 

New Source Performance Standards (NSPS)

Boiler 4 is subject to 40 CFR pt. 60, Subpart D. The proposed new emergency engine generator 

is subject to 40 CFR pt. 60, Subp. IIII. 

National Emission Standards for Hazardous Air Pollutants (NESHAP)

There is a NESHAP that applies to reciprocating internal combustion engines. The new emergency 

engine generator is exempted from the requirements of the standard, other than initial notification 

requirements in 40 CFR § 63.6600. Section 63.6600 exempts emergency/limited use engines, and 

engines that are smaller than 500 horsepower. The new proposed engine meets these two criteria. 

The other existing engines on site are exempt from the standard under the same criteria. There are 

no other NESHAPS that apply to the facility. 40 CFR Part 63 Subpart DDDDD for a major source 

of HAP has been vacated. When DDDDD is promulgated it will apply to the facility. 

Clean Air Mercury Rule CAMR

Removed mercury monitor installation requirement from EU001 and EU002. The Clean Air 

Mercury (CAMR) has been vacated and these monitors are required by rule. Even if the rule was 

still in effect the facility would not be required to install the monitors because stack tests showed 

that the rule would not apply to EU001 and EU002. MPCA staff recommended the removal. 

Minnesota State Rules

Portions of the facility are subject to the following Minnesota Standards of Performance: 

• Minn. R. 7011.0510 Standards of Performance for Existing Indirect Heating Equipment 

• Minn. R. 7011.0515 Standards of Performance for New Indirect Heating Equipment 

• Minn. R. 7011.0710 Standards of Performance for Pre-1969 Industrial Process Equipment 

• Minn. R. 7011.0715 Standards of Performance for Post-1969 Industrial Process Equipment 

• Minn. R. 7011.2300 Standards of Performance for Stationary Internal Combustion Engines 

Mercury Reduction Act

In May of 2006, the State of Minnesota enacted the Mercury Emissions Reduction Act of 2006 

(Minn. Stat. 216B.68 to 216B.687). The Act addresses several methods of reducing mercury 

emissions within the state, including reducing emissions from large electric power generating 

plants. Power plants that have a total net capacity in excess of 500 MW from all units at the site 

must develop plans and implement them at the units that are greater than 100 MW. A schedule 

is established in the Act that differs for dry and wet methods of controlling SO2. This legislation 

affects the two larger units at the Boswell, Units 3 and 4. The Act will eventually require the 

reduction of mercury at targeted units. 
Technical Support Document, Permit Action Number: 06100004 - 004

Page 7 of 21 

Date: 9/18/2009 

There is a requirement for wet and dry scrubbed units to prepare plans for achieving 90 percent 

reduction of mercury from the unit by 2014. Minn. Stat. 216B.6851, subd. 5 encourage early 

action for wet scrubbed units, and sets December 31, 2010 as the early action target date to 

achieve the 90 percent reduction for power boiler No. 3. 

Clean Air Interstate Rule

On July 11, 2008, the DC Circuit Court of Appeals issued an opinion pointing out several “fatal 

flaws” with the Clean Air Interstate Rule. In the opinion, the Court vacated the existing rule. 

However, the Court never issued the mandate – the vehicle that would have explicitly prevented 

CAIR from taking effect. EPA petitioned for rehearing, asking the Court to make substantive 

changes to the July opinion, and to change the remedy from vacatur to simple remand. 

On December 23, 2008, the Court issued a panel opinion that changed the remedy. CAIR was 

remanded to EPA to be rewritten, addressing the flaws identified in the July ruling. However, 

the Court made no substantive changes to its opinion; EPA must therefore address all the flaws 

identified in July. With the remedy changing to a simple remand, the entirety of CAIR goes into 

effect as previously planned (including all parts that the Court identified as flawed.) 

One main issue that EPA needs to address on remand is whether Minnesota should continue to 

be included in CAIR. The Court ruled in July that EPA did not adequately respond to claims 

made by Minnesota Power that data on Minnesota emissions were inaccurate, and that using 

better data would result in Minnesota falling below the threshold impact on a non-attainment 

area that was used to determine inclusion. 

In a letter dated October 31, 2008, from Robert Meyers (Principal Deputy Assistant 

Administrator, Office of Air and Radiation) and Granta Nakayama (Assistant Administrator, 

Office of Enforcement and Compliance Assurance) to Minnesota Power’s counsel, EPA stated: 

[I]t is the U.S. Environmental Protection Agency’s (EPA) intention to publish in the 

Federal Register a rule amending the Clean Air Interstate Rule (CAIR) to stay the 

effectiveness of the rule with respect to sources located in the State of Minnesota. 

That administrative stay will remain in effect until such time as EPA determines 

through a rulemaking under the Clean Air Act whether Minnesota should be 

included in the CAIR region for fine particulate matter. EPA believes that in light of 

the Court’s decision, sources in Minnesota should not be required to make any 

additional expenditures to comply with CAIR prior to the expiration of the 

administrative stay of the rule. 

The Court was aware of this letter when it made its December 23, 2008 decision. 

EPA’s John Mooney from the Region V Office notified the MPCA that on January 15, 2009, the 

USEPA Administrator signed the notice for the proposed rule to stay CAIR requirements in 

Minnesota until the Agency determines whether Minnesota should be in the CAIR region. On 

January 20, 2009, Mr. Rahm Emanuel, Assistant to the President and Chief of Staff, signed a 
Technical Support Document, Permit Action Number: 06100004 - 004

Page 8 of 21 

Date: 9/18/2009 

“Memorandum for the Heads of Executive Departments and Agencies” on the subject of 

“Regulatory Review”. In this memorandum, Mr. Emanuel directs his staff to stop sending 

proposed and final regulations to the Office of the Federal Register (OFR) and to withdraw 

proposed and final regulations from the OFR that have not been published in the Federal 

Register. The proposed rule to stay CAIR requirements in Minnesota has not been published in 

the Federal Register. Copies of the signed proposed rule to stay CAIR requirements in 

Minnesota and its fact sheet can be found at 

http://epa.gov/cair/pdfs/20090114proposal.pdf

http://epa.gov/cair/pdfs/20090114fs.pdf

Please also note that under the proposed rule to stay CAIR in Minnesota, EPA requires that as of 

June 30, 2009, each Minnesota source with recorded allowance allocations under the annual 

NOX trading program must hold an amount of allowances issued for the same year as the 

recorded allowances (e.g., 2009) equal to the amount of the recorded allocations. EPA also 

proposes that the Administrator deduct, and retire, these required allowance holdings and that no 

additional allowance allocations from the state annual NOx trading budget for Minnesota be 

recorded. Although these provisions could be amended after review by staff in President 

Obama’s administration, this should be an important consideration for management of recorded 

allowances by CAIR sources in Minnesota. 

The date for submitting allowances for the 2009 annual NOX program is not until early 2010; 

EPA should be able to promulgate a stay of the rule by that time. However, it is likely to be in 

covered sources best interests to continue to report emissions data quarterly as required by the 

CAIR rule. In addition, Minnesota may be included in the re-promulgated CAIR rule. 

It must be noted that after publication, this remains a proposed rule; a stay of the rule is not 

official until it has gone through the notice and comment rulemaking proceedings in the Federal 

Register. Such public participation and rule promulgation process could take several months. 

Until that time, CAIR is officially in effect in Minnesota. 

Therefore, for the time being, the permits for CAIR affected facilities have a condition at the 

total facility level requesting compliance with CAIR with a sunset provision linked to EPA’s 

future regulatory actions. The MPCA will not go as far as to issue a CAIR permit given the 

current prospects of the CAIR program in Minnesota. 

3. Technical Information

3.1 Clean Air Mercury Rule

Removed mercury monitor installation requirement from EU001 and EU002. The Clean Air 

Mercury (CAMR) has been vacated and these monitors are required by rule. Even if the rule was 

still in effect the facility would not be required to install the monitors because stack tests showed 

that the rule would not apply to EU001 and EU002. Anne Jackson recommended the removal. 
Technical Support Document, Permit Action Number: 06100004 - 004

Page 9 of 21 

Date: 9/18/2009 

3.2 Vendor Certification of Sulfur Content

Removed requirement to calculate SO2 emissions based on vendor certification from EU001 and 

EU002 when on bypass to SV001. The new CEMS for SO2 will be placed after the bag houses 

rather then in SV003, which is the main stack shared by EU001, EU002, and EU003. The 

location of the new CEMS systems allows for continuous tracking whether being vented through 

the main stack SV003 or in the bypass stack SV001. 

3.3 Igniter/Heat Gun Project – Actual To Projected Actual – PSD Analysis

There was sufficient data to determine the baseline actual emissions as defined at 

§52.21(b)(48)(i). Baseline actual emissions are based on fuel usage records and AP-42 emission 

factors. The igniter/heat guns are only used during the startup period of the boilers; they are not 

used during normal operation of the boilers. As a result actual use is less than 1% yearly 

capacity of the guns/igniters. This is why the capacity of the igniter/heat guns is not included on 

the MMBtu/hr design capacity of the boilers. This project does not remove the fuel oil fired 

igniter/guns from the boilers. This project adds a parallel natural gas fired igniter/gun to each of 

the existing fuel oil fired igniter/gun. There will be a physical and electric lockout that allows 

for the use of only one of each pair at any given time. This gives the facility the flexibility to use 

fuel oil or natural gas based on cost. Calculation spreadsheets are found in the attachments to this 

TSD. 

Future projected actual fuel usage rate for the igniters/guns used for this analysis is twice the 

past maximum rate. There are no excludable emissions included in the analysis because the 

natural gas capacity that has been added could not have been “accommodated” prior to the 

installation of the NG igniters. There is not a reasonable possibility that the increase in emissions 

will be significant under §52.21(r)(6)(vi). No documentation or on-going monitoring is required. 

A natural gas usage limit across all boilers is used to avoid a significant increase in CO Potential 

to emit; this can be found under GP 004. The fuel usage limit restricts the increase of CO to 95 

tpy to keep the emissions from the modification under the threshold for a mandatory Air 

Emissions Risk Assessment (AERA). 

3.4 NOx Reduction Project Actual To Projected Actual – PSD Analysis

The Minnesota Pollution Control Agency (MPCA) has received and reviewed the Minnesota 

Power March 21, 2008 letter regarding planned changes at the Minnesota Power (Company) 

Boswell Energy Center for the reduction of nitrogen oxides (NOX) emissions from Units 1, 2, 

and 4. To achieve NOX emissions reductions, the Company intends to install ROFA/Rota Mix 

over-fire air and urea injection in units 1 and 2 in late 2008 and early 2009. 
Technical Support Document, Permit Action Number: 06100004 - 004

Page 10 of 21 

Date: 9/18/2009 

There was sufficient data to determine the baseline actual emissions as defined at 

§52.21(b)(48)(i). Boilers 1 & 2 have been, and will have a high rate of utilization at the facility. 

There is a possibility that the increase in emissions will be significant under §52.21(r)(6)(vi). To 

verify the PM10 emissions assumptions made in the analysis and the calculation of PM10 future 

actual emissions, the MPCA will add requirements for units 1 and 2 PM10 performance testing 

and re-verification of PM10 emissions changes resulting from the addition of the NOX controls. 

The March 21, 2008 letter from Jeff Smith to Minnesota Power which outlined that the MPCA 

had determined that the facility could install the control equipment 

Table 1.1 is a summary of the changes of emissions due to the NOx reduction project. Paved 

road Fugitives are due to the increased truck traffic from hauling in the NOx reducing reagents. 

The pollutants of concern in this analysis are all sizes of particulate emissions. . The baseline 

years used in this analysis are appropriate, the years 05-06 are within the look back period of five 

years. The calculation and use of excludable emissions is correct. The units were permitted and 

capable of running at a higher rate during the baseline period. The theoretical increases of PM, 

PM10 and PM2.5 are well below their significance thresholds of 40, 25 and 15 respectively. The 

emissions factors of particulates are based on best engineering estimates. To ensure that this 

project has not crossed a PSD significance thresholds 

3.5 Maximum achievable operating rate

This permit amends the maximum achievable operating rates for boilers 3 and 4 (EU003, 

EU004). These updates stem from recent stack tests. Further discussions with the facility 

revealed that these boilers are consistently run at these updated rates. The previous rates used 

for PTE calculations and modeling were based on the boiler manufacturer guaranteed rate. The 

updated MMBtu/hr values come from coal Btu tests and throughput during a stack test. The 

change in rated capacity does not change what regulations and limits that the facility and boilers 

are subject to. 

3.6 Title V Modeling: Results and discussion

Modeling results showed that the facility is well under the NAAQ and MAAQ standards. The 

parameters used in modeling have been reviewed and deemed expectable by the permitting and 

modeling staff. Results are summarized in the tables below. 

 Minnesota Ambient Air Quality Standards (μg/m3): 

Criteria Pollutants 1-Hour 3-Hour 8-Hour 24-Hour Annual Other 

CO 35,000 - 10,000 - - - 

NOX - - - - 100 - 

PM2.5 - - - 35 15 - 

PM10 - - - 150 50 - 

SO2 1,300 1,300 - 365 60 - 

SO2 (Northern MN) - 915 - - - - 

 Predicted Impacts including Monitored Background Concentrations (μg/m3): 
Technical Support Document, Permit Action Number: 06100004 - 004

Page 11 of 21 

Date: 9/18/2009 

Criteria Pollutants 1-Hour 3-Hour 8-Hour 24-Hour Annual Other 

CO NA - NA - - - 

NOX - - - - 72.7 - 

PM2.5 - - - NA NA - 

PM10 - - - 60.8 25.9 - 

SO2 692.9 NA - 205.9 13.2 - 

SO2 (Northern MN) - 526.9 - - - - 

The pollutant that is closest to the standard is NOx. The permit deviates from guidance by 

putting NOx under Tier 2 modeling rather than Tier 1. The cutoff value is normally 75% of 

standard and the modeling rate in under that at 72.7%. This permit amends the maximum 

operating rate for boiler 3 & 4. Using these amended values would most likely push the NOx 

impact above 75% of the standard. There is little to no chance that remodeling using the 

amended MMBtu/hr would result in NAAQS violations. Moving to Tier 2 is more stringent and 

will require remodeling if the facility submits a major amendment that increases NOx emissions. 

3.7 Revised PSD Modeling For the Larger EGU (EU 023): Results and discussion

Modeling results showed that the facility is well under the NAAQ and MAAQ standards. The 

parameters used in modeling have been reviewed and deemed expectable by the permitting and 

modeling staff. Results are summarized in the tables below. 

 SIL Values (μg/m3): 

Criteria Pollutants 1-Hour 3-Hour 8-Hour 24-Hour Annual Other 

CO 2,000 - 500 - - - 

NOX - - - - 1.0 - 

PM2.5 (option 3) - - - 1.2 0.3 - 

PM10 - - - 5.0 1.0 - 

SO2 25.0 25.0 - 5.0 1.0 - 

SO2 (Northern MN) - 25.0 - - - - 

Other 

Predicted Impacts 

(μg/m3): 

Criteria Pollutants 1-Hour 3-Hour 8-Hour 24-Hour Annual Other 

CO 241.3 - 118.4 - - - 

NOX - - - - NA - 

PM2.5 - - - NA NA - 

PM10 - - - NA NA - 

SO2 NA NA - NA NA - 

SO2 (Northern MN) - NA - - - - 

Other 

PSD modeling for CO was revised because of the resizing of an emergency generator that was 

involved in the original analysis. The contribution of CO from the emergency generator is 

relatively small. EU003 was the primary contributor to the CO increase was due to pollution 
Technical Support Document, Permit Action Number: 06100004 - 004

Page 12 of 21 

Date: 9/18/2009 

control added to reduce NOx and SO2 emissions. The resized emergency generator does not 

change the result of the PSD analysis and modeling conducted for PER 003. 

3.8 Calculations of Potential to Emit and Emissions Increase Analysis

Attachment 1 contains detailed spreadsheets of the facility’s potential to emit and emissions 

summary prepared by the MPCA and the Permittee. 

Attachment 2 to this TSD contains the emissions calculations related to the NOx reduction 

project, which installed OFA and NSCR on boilers 1 and 2 including Title I net emissions 

increase calculations for this modification. This demonstrates that this modification is not a 

major modification for PSD. The attachment also contains the non-Title I calculations for this 

modification which demonstrate that the modification trigger an AERA or EAW. 

Attachment 3 contains the emissions calculations related to the Igniter/heat gun project on all 

four boilers at the facility. Title I net emissions increase calculations for this modification. This 

demonstrates that this modification is not a major modification for PSD. The attachment also 

contains the non-Title I calculations for this modification which demonstrate that the 

modification is not submit to an AERA or EAW. 

Attachment 4 contains the emissions calculations related to the revised CO PSD analysis due to 

the increased size of the emergency generator EU 023 for boiler 3. 

3.9 slag shock system

This permit also incorporates a propane fired slag shock system. This system qualifies as an 

insignificant modification due to emissions. The system will be installed to target tougher-toremove slag deposits by using the percussion of a small controlled explosion to shock the 

deposits off of the boiler. Since the system will operate within the boiler propane has to be 

added to the allowable fuels list for all boilers at the facility. Calculations for this system can be 

found in attachment 7 to this TSD. 

4 Periodic Monitoring

In accordance with the Clean Air Act, it is the responsibility of the owner or operator of a facility 

to have sufficient knowledge of the facility to certify that the facility is in compliance with all 

applicable requirements. 

In evaluating the monitoring included in the permit, the MPCA considers the following: 

• The likelihood of violating the applicable requirements; 

• Whether add-on controls are necessary to meet the emission limits; 

• The variability of emissions over time; 

• The type of monitoring, process, maintenance, or control equipment data already 

available for the emission unit; 
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Date: 9/18/2009 

• The technical and economic feasibility of possible periodic monitoring methods; and 

• The kind of monitoring found on similar units elsewhere. 

Table 4.1 summarizes the periodic monitoring requirements for those emission units for which 

the monitoring required by the applicable requirement is nonexistent or inadequate. 

Table 4.1 Periodic Monitoring 

Emission 

Unit or 

Group 

Requirement (basis) Additional Monitoring Discussion

GP004 SO2 limits for SV001, 002, 003, 

and 004 

CEM Continuous CEMs data 

ensures compliance with 

SO2 Limits. 

SV004 SV004 gas exit temperature 

This minimum temperature 

requirement is necessary to 

ensure adequate emissions 

dispersion. 

Measured and recorded 

hourly 

Hourly gas temperature 

readings ensure that the 

facility is operating with 

dispersion characteristics 

used for modeling analysis 

EU001 PM < 0.1 lb/MMBtu 

based on PSD modeling 

40 CFR Section 52.21(k) 

Monitoring, I and M, 

stack emission testing, 

and recordkeeping for 

fabric filter plus CAM 

requirements 

Initial performance testing 

has been completed. Based 

on the results, a test 

frequency of every 60 

months has been established. 

CAM requirements ensure 

that the control equipment is 

operated and maintained 

properly. 

 Opacity < 20 % with exception 

Minn. R. 7011.0510, subp. 2 

COM The use of a Continuous 

Opacity Monitor ensures 

that opacity limit will be 

followed. 

 SO2 < 4 lb/MMBtu for solid 

fuel, 2 lb/MMBtu for liquid 

Minn. R. 7011.0510, subp. 1 

CEM Continuous CEMs data 

ensures compliance with 

SO2 Limits. Federal acid 

rain monitoring applies. 

Violation of this limit is 

unlikely. 

 SO2 < 1.18 lb/mmBtu when 

emissions are vented through 

SV001 

CEM Continuous CEMs data 

ensures compliance with 

SO2 Limits.

 NOx limits and averaging plan CEM Continuous CEMs data 

ensures compliance with 

NOx Limits. Federal acid 
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Date: 9/18/2009 

Emission 

Unit or 

Group 

Requirement (basis) Additional Monitoring Discussion

rain monitoring applies 

EU002 PM < 0.1 lb/MMBtu 

based on PSD modeling 

40 CFR Section 52.21(k) 

Monitoring, I and M, 

stack emission testing, 

and recordkeeping for 

fabric filter plus CAM 

requirements 

Initial performance testing 

has been completed. Based 

on the results, a test 

frequency of every 60 

months has been established. 

CAM requirements ensure 

that the control equipment is 

operated and maintained 

properly. 

 Opacity < 20 % with exception 

Minn. R. 7011.0510, subp. 2 

COM The use of a Continuous 

Opacity Monitor ensures 

that opacity limit will be 

followed. 

 SO2 < 4 lb/MMBtu for solid 

fuel, 2 lb/MMBtu for liquid 

Minn. R. 7011.0510, subp. 1 

CEM Continuous CEMs data 

ensures compliance with 

SO2 Limits. Federal acid 

rain monitoring applies. 

Violation of this limit is 

unlikely. 

 SO2 < 1.18 lb/mmBtu when 

emissions are vented through 

SV001 

CEM Continuous CEMs data 

ensures compliance with 

SO2 Limits.

 NOx limits and averaging plan CEM Continuous CEMs data 

ensures compliance with 

NOx Limits. Federal acid 

rain monitoring applies 

EU003 

Boiler 3 

prior to 

modificatio

ns 

PM < 0.6 lb/MMBtu 

Minn. R. 7011.0510, subp. 1 

Monitoring, I and M, 

and recordkeeping for 

wet scrubber plus CAM 

requirements 

Stack test due 180 after 

modification is complete 

will set a test frequency plan 

that will confirm continuous 

compliance with this limit. 

CAM requirements ensure 

that the control equipment is 

operated and maintained 

properly. 

 Opacity < 20% with exceptions COM The use of a Continuous 

Opacity Monitor ensures 

that opacity limit will be 

followed. 
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Date: 9/18/2009 

Emission 

Unit or 

Group 

Requirement (basis) Additional Monitoring Discussion

 SO2 < 4 lb/MMBtu for solid 

fuel, 2 lb/MMBtu for liquid 

Minn. R. 7011.0510, subp. 1 

CEM Continuous CEMs data 

ensures compliance with 

SO2 Limits. Federal acid 

rain monitoring applies. 

Violation of this limit is 

unlikely. 

 SO2 < 2.97 lb/MMBtu as 1-hr 

avg. when EU001 and EU002 are 

also operating and vented 

through SV001 

Minn. R. 7009.0020 

CEM Continuous CEMs data 

ensures compliance with 

SO2 Limits.

 NOx < 0.45 lb/MMBtu annual 

avg. 

CEM Continuous CEMs data 

ensures compliance with 

NOx Limits. 

EU003 

After 

modificatio

ns 

PM < 0.014 lb/MMBtu 

BART 

Monitoring, I and M, 

stack performance 

testing, and 

recordkeeping for fabric 

filer plus CAM 

requirements 

Stack test due 180 after 

modification is complete 

will set a test frequency plan 

that will confirm continuous 

compliance with this limit. 

CAM requirements ensure 

that the control equipment is 

operated and maintained 

properly. 

 PM10 < 0.035 lb/mmBtu 

BART 

Monitoring, I and M, 

stack performance 

testing and 

recordkeeping for fabric 

filer plus CAM 

requirements 

Stack test due 180 after 

modification is complete 

will set a test frequency plan 

that will confirm continuous 

compliance with this limit. 

CAM requirements ensure 

that the control equipment is 

operated and maintained 

properly. 

 SO2 < 0.09 lb/MMBtu 

BART 

CEM Continuous CEMs data 

ensures compliance with 

SO2 Limits.
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Date: 9/18/2009 

 NOx < 0.07 lb/MMBtu 30 day 

rolling 

BART 

CEM Continuous CEMs data 

ensures compliance with 

NOx Limits. 

 Hydrogen fluoride < 0.0018 

lb/mmBtu 

Title I Condition 

Periodic stack emission 

testing 

Initial stack test after 

modification will set a test 

frequency that will confirm 

compliance with this limit. 

 CO < 0.15 lb/mmBtu 

BACT 

CEM Continuous CEMs data 

ensures compliance with 

CO Limits. 

 Lead < 0.00004 lb/mmBtu Period stack emission 

testing, operation and 

monitoring of control 

equipment 

Initial stack test after 

modification will set a test 

frequency that will confirm 

compliance with this limit. 

Operation and maintenance 

of control equipment will 

ensure that this limit is met. 

EU004 PM < 0.1 lb/MMBtu 

40 CFR § 52.21 BACT limit 

Period stack emission 

testing, Monitoring, I 

and M, and 

recordkeeping for ESP 

plus CAM requirements 

Initial performance testing 

has been completed. Based 

on the results, a test 

frequency of every 60 

months has been established. 

CAM requirements ensure 

that the control equipment is 

operated and maintained 

properly. 

 Opacity < 20 % with exception 

40 CFR Section 60.42(a)(2) 

COM The use of a Continuous 

Opacity Monitor ensures 

that opacity limit will be 

followed. 

 SO2 < 1.2 lb/MMBtu for solid 

fuel 

SO2 < 0.8 lb/MMBtu for liquid 

fuel 

40 CFR § 52.21 BACT limit 

and 40 CFR § 60.43 

CEM Continuous CEMs data 

ensures compliance with 

SO2 Limits.

 NOx < 0.7 lb/MMBtu for solid 

fuel 

NOx < 0.3 lb/MMBtu for solid 

fuel 

CEM Continuous CEMs data 

ensures compliance with 

NOx Limits. 
Technical Support Document, Permit Action Number: 06100004 - 004

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Date: 9/18/2009 

40 CFR § 52.21 BACT limit 

EU005 None None Particulate emissions due to 

drift loss are limited by 

proper operating practices to 

limit total dissolved solids in 

cooling water 

EU006 None None Particulate emissions due to 

drift loss are limited by 

proper operating practices to 

limit total dissolved solids in 

cooling water 

EU007 

EU009 

EU010 

Opacity < 20 % 

Minn. R. 7011.2300 

None Internal combustion engines 

for backup electrical 

generators. Opacity 

unlikely to be exceeded with 

fuel specifications and 

engines are limited use. 

 SO2 < 0.5 lb/MMBtu None Use of diesel fuel oil 

guarantees compliance with 

the limit 

EU011 PM < IPER 

Minn. R. 7011.0710 

Monitoring, I and M, 

and recordkeeping for 

fabric filter 

Due to the nature of the 

material that is being 

handled and the control 

equipment that is being used 

it is unlikely that the limit 

will be violated. 

EU012 PM < IPER 

Minn. R. 7011.0710 

Monitoring, I and M, 

and recordkeeping for 

fabric filter 

Due to the nature of the 

material that is being 

handled and the control 

equipment that is being used 

it is unlikely that the limit 

will be violated. 

EU013 PM < IPER 

Minn. R. 7011.0710 

Monitoring, I and M, 

and recordkeeping for 

fabric filter 

Due to the nature of the 

material that is being 

handled and the control 

equipment that is being used 

it is unlikely that the limit 

will be violated. 

EU014 PM < IPER 

Minn. R. 7011.0710 

Monitoring, I and M, 

and recordkeeping for 

fabric filter 

Due to the nature of the 

material that is being 

handled and the control 

equipment that is being used 

it is unlikely that the limit 
Technical Support Document, Permit Action Number: 06100004 - 004

Page 18 of 21 

Date: 9/18/2009 

will be violated.

EU015 PM < 0.01 gr/dscf 

Title I Condition 

Monitoring, I and M, 

and recordkeeping for 

fabric filter 

Due to the nature of the 

material that is being 

handled and the control 

equipment that is being used 

it is unlikely that the limit 

will be violated.

EU016 PM < 0.01 gr/dscf 

Minn. R. 7009 and Minn. R. 

7011.0715 

Monitoring, I and M, 

and recordkeeping for 

fabric filter 

Due to the nature of the 

material that is being 

handled and the control 

equipment that is being used 

it is unlikely that the limit 

will be violated. 

EU017 PM < 0.005 gr/dscf 

Minn. R. 7009 and Minn. R. 

7011.0715 

Monitoring, I and M, 

and recordkeeping for 

fabric filter 

Due to the nature of the 

material that is being 

handled and the control 

equipment that is being used 

it is unlikely that the limit 

will be violated. 

EU018 PM < IPER 

Minn. R. 7009 and Minn. R. 

7011.0715 

Monitoring, I and M, 

and recordkeeping for 

fabric filter 

Due to the nature of the 

material that is being 

handled and the control 

equipment that is being used 

it is unlikely that the limit 

will be violated. 

EU019 PM < 0.005 gr/dscf 

Title I Condition 

Monitoring, I and M, 

and recordkeeping for 

fabric filter 

Due to the nature of the 

material that is being 

handled and the control 

equipment that is being used 

it is unlikely that the limit 

will be violated. 

EU020 PM < 0.005 gr/dscf 

Minn. R. 7009 and Minn. R. 

7011.0715 

Monitoring, I and M, 

and recordkeeping for 

fabric filter 

Due to the nature of the 

material that is being 

handled and the control 

equipment that is being used 

it is unlikely that the limit 

will be violated. 

EU021 PM < 0.005 gr/dscf 

Minn. R. 7009 and Minn. R. 

7011.0715 

Monitoring, I and M, 

and recordkeeping for 

fabric filter 

Due to the nature of the 

material that is being 

handled and the control 

equipment that is being used 

it is unlikely that the limit 

will be violated. 

EU023 Limits set by Subp. IIII Operation and 
Technical Support Document, Permit Action Number: 06100004 - 004

Page 19 of 21 

Date: 9/18/2009 

monitoring set by 

regulation 

 SO2 < 0.5 lb/MMBtu Sulfur content of fuel Use of diesel fuel oil 

guarantees compliance with 

the limit 

 Carbon Monoxide < 3.0 grams 

per kilowatt-hour. BACT limit 

Stack test, engine 

design. 

Stack test will confirm 

compliance with this limit. 

 

4.2 Insignificant Activities

Minnesota Power Boswell has several operations which are classified as insignificant activities. 

These are listed in the Appendix to the permit. 

Activity Applicable 

Regulations 

Discussion

Grinders Minn. R. 

7007.1300, subp. 3.D.(2) 

Minn. R. 

7011.0715 

For these units, based on EPA published emissions 

factors, it is highly unlikely that they could violate the 

applicable requirement. In addition, these units are 

typically operated and vented inside a building, so 

testing for PM or opacity is not feasible.

Gasoline Tanks Minn. R. 

7007.1300, subp. 3.E(1) 

Minn. R. 

7007.1300, subp. 

3.E(1) 

It is highly unlikely that they could violate the 

applicable requirement. 

Welding Equipment Minn. 

R. 7007.1300, subp. 3.H(4) 

Minn. R. 

7011.0715 

For these units, based on EPA published emissions 

factors, it is highly unlikely that they could violate the 

applicable requirement. In addition, these units are 

typically operated and vented inside a building, so 

testing for PM or opacity is not feasible.

Sandblasting Minn. R. 

7007.1300, subp. 4.B(2) 

Minn. R. 

7011.0715 

For these units, based on EPA published emissions 

factors, it is highly unlikely that they could violate the 

applicable requirement. In addition, these units are 

typically operated and vented inside a building, so 

testing for PM or opacity is not feasible.

Coal Stockpile loading 

Minn. R. 7007.1300, subp. 

4.B(2) 

Minn. R. 

7011.0150 

This activity qualifies as conditional insignificant. It 

is highly unlikely that they could violate the 

applicable requirement.

Coal Stockpile, equipment 

traffic Minn. R. 7007.1300, 

subp. 4.B(2) 

Minn. R. 

7011.0150 

This activity qualifies as conditional insignificant. It 

is highly unlikely that they could violate the 

applicable requirement.

Conveyor drop onto 

stockpile, reclaimer Minn. 

R. 7007.1300, subp. 4.B(2) 

Minn. R. 

7011.0150 

This activity qualifies as conditional insignificant. It 

is highly unlikely that they could violate the 

applicable requirement.

Conveyor Drop onto 

Stockpile –Side Chute Minn. 

Minn. R. 

7011.0150 

This activity qualifies as conditional insignificant. It 

is highly unlikely that they could violate the 
Technical Support Document, Permit Action Number: 06100004 - 004

Page 20 of 21 

Date: 9/18/2009 

R. 7007.1300, subp. 4.B(2) applicable requirement.

Rail Car Unloading Minn. 

R. 7007.1300, subp. 4.B(2) 

Minn. R. 

7011.0150 

This activity qualifies as conditional insignificant. It 

is highly unlikely that they could violate the 

applicable requirement.

Rail Car Load Out Minn. R. 

7007.1300, subp. 4.B(2) 

Minn. R. 

7011.0150 

This activity qualifies as conditional insignificant. It 

is highly unlikely that they could violate the 

applicable requirement.

Lab Hoods (4) Minn. R. 

7007.1300, subp. 4.B(2) 

Minn. R. 

7011.0715 

This activity qualifies as conditional insignificant. It 

is highly unlikely that they could violate the 

applicable requirement.

Coal Transfer Tower A 

Minn. R. 7007.1300, subp. 

4.B(2) 

Minn. R. 

7011.0150 

This activity qualifies as conditional insignificant. It 

is highly unlikely that they could violate the 

applicable requirement.

Coal Transfer Tower B 

Minn. R. 7007.1300, subp. 

4.B(2) 

Minn. R. 

7011.0150 

This activity qualifies as conditional insignificant. It 

is highly unlikely that they could violate the 

applicable requirement.

Coal Conveyer Belt C3 

Minn. R. 7007.1300, subp. 

4.B(2) 

Minn. R. 

7011.0150 

This activity qualifies as conditional insignificant. It 

is highly unlikely that they could violate the 

applicable requirement.

Coal Rotary Car Dumper 

Minn. R. 7007.1300, subp. 

4.B(2) 

Minn. R. 

7011.0150 

This activity qualifies as conditional insignificant. It 

is highly unlikely that they could violate the 

applicable requirement.

Coal Rotary Car TP Minn. R. 

7011.0150 

This activity qualifies as conditional insignificant. It 

is highly unlikely that they could violate the 

applicable requirement.

Coal Transfer and Sampling 

House Minn. R. 7007.1300, 

subp. 4.B(2) 

Minn. R. 

7011.0150 

This activity qualifies as conditional insignificant. It 

is highly unlikely that they could violate the 

applicable requirement.

Coal Storage Silo Minn. R. 

7007.1300, subp. 4.B(2) 

Minn. R. 

7011.0715 

This activity qualifies as conditional insignificant. It 

is highly unlikely that they could violate the 

applicable requirement.

Coal Tripper Transfer Minn. 

R. 7007.1300, subp. 4.B(2) 

Minn. R. 

7011.0715 

This activity qualifies as conditional insignificant. It 

is highly unlikely that they could violate the 

applicable requirement.

#4 Coal Bunker Minn. R. 

7007.1300, subp. 4.B(2) 

Minn. R. 

7011.0715 

This activity qualifies as conditional insignificant. It 

is highly unlikely that they could violate the 

applicable requirement.

5. Permit Organization

In general, the permit meets the MPCA Delta Guidance for ordering and grouping of 

requirements. One area where this permit deviates slightly from Delta guidance is in the use of 

appendices. While appendices are fully enforceable parts of the permit, in general, any 
Technical Support Document, Permit Action Number: 06100004 - 004

Page 21 of 21 

Date: 9/18/2009 

requirement that the MPCA thinks should be tracked (e.g., limits, submittals, etc.), should be in 

Table A or B. The main reason is that the appendices are word processing sections and are not 

part of the tracking system. Violation of the appendices can be enforced, but the computer 

system will not automatically generate the necessary enforcement notices or documents. Staff 

must generate these. 

Deviation from normal format: Alternate Operating Scenarios for SO2 and NOx monitors. 

6. Comments Received

Public Notice Period: May 21, 2009 - June 22, 2009 

EPA 45-day Review Period: May 21, 2009 - July 7, 2009 

Comments were not received from the public during the public notice period. 

Comments were not received from EPA during their review period. 

7. Conclusion 

Based on the information provided by <>, the MPCA has reasonable assurance that the proposed 

operation of the emission facility, as described in the Air Emission Permit No. 06100004-004 

and this technical support document, will not cause or contribute to a violation of applicable 

federal regulations and Minnesota Rules. 

Staff Members on Permit Team: Benjamin klismith (permit writer/engineer) 

 Steve Palzkill (enforcement) 

 Andrew Place (stack testing) 

 Marshall Cole (peer reviewer) 

AQ File No. 73B; DQ 2218, 2232, 2342, 1601, 2007, 2085, 2261 

Attachments: 1. PTE calculation and emissions summary 

2. NOx reduction project calculation spreadsheets 

3. Igniter/Heat gun project calculation spreadsheets 

4. Generator project calculation spreadsheets 

5. Facility description and CD-01 Forms 

6. NOx reduction project letter from MPCA to facility 

7. Slag shock system calculations 

OMB 2060-0631 Part I Question 14a

Minnesota Power Boswell Energy Center (1893)Materials listed in the permitBoswell "Other" Material Permitted to burn Actually burn Quantity / yea

5% of total mass inputoxygen limited to 3% or greateragents may only be burned while boiler operating at 75% of rated capacity or greater

Oily coal NA no - Used oil Not to exceed 17.5% of rated heat input on an hourly basis (equal to 963 gallsons/hr) no - 

Oily paper-based floor dry NA yes 8525 Propane NA No - 

Unit 3 Same as Units 1&2, plus...

Used oil Not to exceed 2,456 gallons/hour no - Wastewater treatment plant sludge Requires performance testing No - Oily materials (includes mixtures of earth substrate (soil, rocks, sod, etc.) Requires performance testing No - 

Man-made petroleum adsorption materialVarious petroleum derived fuels (hydraulic, transformer (less than 50 ppm PCB)

Crankcase or lubricating oils no - Diesel fuel no - Crude oil no - 

Unit 4 Same as Units 1 & 2, but

Used oil Not to exceed 3824 gallons/hour (10% of rated capacity of 5,109 mmBtu/hour) no - 

tracked with oily floor dry above 

whole facility for spilled oils/f

Boiler cleaning agents (EDTA type and Ammonium Bromate, generated onsite)

If "other" was checked in questions 10 or 11 above indicating that any non-fossil fuel or other material (including, but not limited to, plastics, treated wood, rubor gaskets, whole tires, tire-derived fuel, boiler cleaning solutions, animal wastes, etc.) is either utilized or permitted to be used, please indicate below what mcombusted in the boiler and in what quantities (specify whether this quantity is on a weight percentage or heat [Btu] basis). Also indicate (yes/no) whether yopermitted to burn non-fossil fuel(s) or other material(s) even if you do not actually burn them. 

No - 

Unit 1 and 

Unit 2
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

A B C D E F G H I J

OMB 2060-0631 Part I Question 15: Identification (or designation) of all coal- and oil-fired steam generating units (boilers) (as defined by Clean Air Act section 112(2)(8)) located at this facility)

Minnesota Power Boswell Energy Center (1893)

Facility Name

Subpart EIA Plant Code

Q 15.01 Boiler ID Unit 1 Unit 2 Unit 3 Unit 4

Q 15.02 Original design fuel (i.e. coal rank or type of oil)

Western subbituminous coal2Western subbituminous coal2

Sub-bituminous 

coal Sub-bituminuous "C"

Q 15.03 Design heat input (mmBtu/hr)1654 654 3344 5062

Q 15.04 Present maximum heat input, (mmBtu/hr)3750 750 4115 5947

Q 15.05 MWe gross capacity summer 73 72 371.3 587.5

Q 15.06 MWe Net capacity summer 67.5 66.9 352 536

Q 15.07 Original design gross efficiency (%, HHV) 88 (11500btu/lb) 88 (11500btu/lb) 86.6 (8648btu/lb) 87.6 (8287btu/lb)

Q 15.08 Present operating gross efficiency (%, HHV) 80 (9076btu/lb) 81 (9058btu/lb) 87.5 (8978btu/lb) 86 (9087btu/lb)

Q 15.09 Design steam pressure (psig)11450 1450 2520 2520

Q 15.10 Operating steam pressure (psig) 1450 1450 2520 2520

Q 15.11 Design steam temperature (°F)11005 1005 1005 1005

Q 15.12 Operating steam temperature (°F) 1005 1005 1005 1005

Q 15.13 Design steam reheat temperature (°F)11005 1005 1005 1005

Q 15.14 Operating steam reheat temperature (°F) 1005 1005 1005 1005

Q 15.15 Fuel

Q 15.16 Hours/year operated 8001.67 7861 6830.33 7611.33

Q 15.17 Average annual capacity factor for the past 3 years 88.59 85.77 78.36 89.78

- - - 40 CFR pt. 60, Subpart D

Q 15.19 Estimated year of retirement Minnesota Power has no scheduled or planned retirement dates for any of our units

1Original design values based on boiler acquisition contracts and/or heat balance drawings. Design heat input does not represent maximum capacity at the time of unit commissioning. 

2Boswell 1&2 were originally built to burn eastern bituminous coal, but were converted in the late 1960s to burn western sub-bituminous coal. Design HHV provided for the eastern coal.

3Current heat input data from Title V permit application does not represent maximum heat input capacity. 

Q 15.18 Applicable NSPS

Boswell Energy Center

1893

 40 CFR Part 60 Subpart Y 

>99% coal, <1%other
OMB 2060-0631 Part I Question 16: Emission Control Technology

Minnesota Power Boswell Energy Center (1893)

Designate the order of the emission controls -- 1 for first control following the boiler, 2 for second control following the boiler, etc.

Plant ID Boiler 

ID Type NOx Control In-service Date SO2 Control In-service Date PM Control In-service Date Other Control In-service Date

Boswell 1 Wall-fired 2 - ROFA / SNCR 2009 Low sulfur coal - 3 - Baghouse 1977 None -

1893 1 Wall-fired 1 - LNB 1998

2 Wall-fired 2 - ROFA / SNCR 2008 Low sulfur coal - 3 - Baghouse 1977 None -

2 Wall-fired 1 - LNB 1997

3 Tangentially-fired 1 - Low Nox Burners and 2 - SCR* 2009 3 - Wet (limestone) FGD 2009 4 - Baghouse 2009 3 - ACI for Hg 2010

4 Tangentially-fired 1 - SNCR 2009 3 - FGD 1980 2 - Wet venturi scrubber 1980 None -

*More information on the Boswell Unit 3 SCR: Answers

Type of material from which the catalyst is manufactured? Titanium Oxide

Type of reductant used in with the SCR (e.g., anhydrous ammonia, aqueous ammonia, urea, other)? Aqueous ammonia

Is the catalyst specifically designed to reduce SO3 formation? Yes, SO3 production was guaranteed at 3.1% or less 
OMB 2060-0631 Part I Question 22: Guaranteed Emission Rate

Minnesota Power Boswell Energy Center (1893)

PM PM10 PM2.5 SO2 HCl and/or 

HF HCN Metal HAP Hg CO

Other 

organics 

(specify)

Other 

pollutant 

(specify)

1

0.01 

grains/SCF 

(99.3%)

2

0.01 

grains/SCF 

(99.3%)

3

0.08 lb/mmBtu 

filterable plus 

condensible, 0.012 

lb/mmBtu filterable

98% HF = 90% 200 ppm

4

0.03 grns/SCF 

(dry basis)

450 ppm (by 

volume dry basis) 200 ppm

Most recent guaranteed emission rate for each pollutant for which there is a permitted emission limit

Plant ID Boiler ID

Boswell 

(1893)
OMB 2060-063 Part II Questions 2-3

Coal Shipments - Minnesota Power Boswell Energy Center (1893)

Train ID Tons Boiler ID# State County Coal Seam

Fuel Ship 

Method Sulfur Ash Btu/Lb Mercury Chlorine Fluorine Nickel Other

RBMCOB201 13,564.000 1,2,3,4 MT Rosebud Rosebud RR 0.630 8.620 8,699 N/A N/A N/A N/A N/A

RBMCOB202 14,041.000 1,2,3,4 MT Rosebud Rosebud RR 0.750 8.490 8,741 N/A N/A N/A N/A N/A

RBMCOB203 13,801.000 1,2,3,4 MT Rosebud Rosebud RR 0.720 8.410 8,749 N/A N/A N/A N/A N/A

RBMCOB204 12,241.000 1,2,3,4 MT Rosebud Rosebud RR 0.590 8.230 8,724 N/A N/A N/A N/A N/A

RBMCOB205 13,204.000 1,2,3,4 MT Rosebud Rosebud RR 0.700 9.050 8,600 N/A N/A N/A N/A N/A

RBMCOB206 13,801.000 1,2,3,4 MT Rosebud Rosebud RR 0.650 8.860 8,736 N/A N/A N/A N/A N/A

RBMCOB207 14,040.000 1,2,3,4 MT Rosebud Rosebud RR 0.710 8.820 8,758 N/A N/A N/A N/A N/A

RBMCOB208 13,200.000 1,2,3,4 MT Rosebud Rosebud RR 0.630 8.530 8,686 N/A N/A N/A N/A N/A

RBMCOB209 13,801.000 1,2,3,4 MT Rosebud Rosebud RR 0.650 9.120 8,561 N/A N/A N/A N/A N/A

RBMCOB210 14,522.000 1,2,3,4 MT Rosebud Rosebud RR 0.820 8.920 8,693 N/A N/A N/A N/A N/A

RBMCOB211 12,960.000 1,2,3,4 MT Rosebud Rosebud RR 0.620 8.410 8,683 N/A N/A N/A N/A N/A

RBMCOB212 13,112.000 1,2,3,4 MT Rosebud Rosebud RR 0.590 9.030 8,596 N/A N/A N/A N/A N/A

RBMCOB213 14,760.000 1,2,3,4 MT Rosebud Rosebud RR 0.670 9.520 8,599 N/A N/A N/A N/A N/A

RBMCOB214 13,801.000 1,2,3,4 MT Rosebud Rosebud RR 0.620 9.310 8,578 N/A N/A N/A N/A N/A

RBMCOB215 14,400.000 1,2,3,4 MT Rosebud Rosebud RR 0.640 9.450 8,602 N/A N/A N/A N/A N/A

RBMCOB216 12,807.000 1,2,3,4 MT Rosebud Rosebud RR 0.650 9.110 8,533 N/A N/A N/A N/A N/A

RBMCOB217 13,801.000 1,2,3,4 MT Rosebud Rosebud RR 0.650 8.750 8,571 N/A N/A N/A N/A N/A

RBMCOB218 14,280.000 1,2,3,4 MT Rosebud Rosebud RR 0.800 9.150 8,541 N/A N/A N/A N/A N/A

RBMCOB219 13,801.000 1,2,3,4 MT Rosebud Rosebud RR 0.670 8.480 8,673 N/A N/A N/A N/A N/A

RBMCOB221 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.780 8.990 8,579 N/A N/A N/A N/A N/A

RBMCOB222 13,560.000 1,2,3,4 MT Rosebud Rosebud RR 0.640 8.900 8,579 N/A N/A N/A N/A N/A

RBMCOB220 13,801.000 1,2,3,4 MT Rosebud Rosebud RR 0.780 8.930 8,551 N/A N/A N/A N/A N/A

RBMCOB223 13,801.000 1,2,3,4 MT Rosebud Rosebud RR 0.610 8.350 8,675 N/A N/A N/A N/A N/A

RBMCOB224 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.610 8.150 8,656 N/A N/A N/A N/A N/A

RBMCOB225 13,921.000 1,2,3,4 MT Rosebud Rosebud RR 0.680 8.480 8,670 N/A N/A N/A N/A N/A

RBMCOB226 13,802.000 1,2,3,4 MT Rosebud Rosebud RR 0.610 8.940 8,533 N/A N/A N/A N/A N/A

RBMCOB227 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.660 9.080 8,536 N/A N/A N/A N/A N/A

RBMCOB228 14,040.000 1,2,3,4 MT Rosebud Rosebud RR 0.610 8.690 8,539 N/A N/A N/A N/A N/A

RBMCOB229 14,160.000 1,2,3,4 MT Rosebud Rosebud RR 0.580 8.300 8,826 N/A N/A N/A N/A N/A

RBMCOB230 13,921.000 1,2,3,4 MT Rosebud Rosebud RR 0.620 8.360 8,739 N/A N/A N/A N/A N/A

RBMCOB231 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.600 8.250 8,543 N/A N/A N/A N/A N/A

RBMCOB232 13,810.000 1,2,3,4 MT Rosebud Rosebud RR 0.620 8.380 8,625 N/A N/A N/A N/A N/A

RBMCOB233 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.590 8.710 8,573 N/A N/A N/A N/A N/A

RBMCOB234 13,808.000 1,2,3,4 MT Rosebud Rosebud RR 0.730 8.730 8,518 N/A N/A N/A N/A N/A

RBMCOB235 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.670 8.390 8,554 N/A N/A N/A N/A N/A

RBMCOB236 13,803.000 1,2,3,4 MT Rosebud Rosebud RR 0.670 8.590 8,752 N/A N/A N/A N/A N/A

RBMCOB237 13,804.000 1,2,3,4 MT Rosebud Rosebud RR 0.690 8.650 8,727 N/A N/A N/A N/A N/A

RBMCOB238 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.610 8.740 8,828 N/A N/A N/A N/A N/A
RBMCOB239 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.700 8.960 8,690 N/A N/A N/A N/A N/A

RBMCOB240 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.650 8.540 8,815 N/A N/A N/A N/A N/A

RBMCOB241 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.700 8.980 8,712 N/A N/A N/A N/A N/A

RBMCOB242 14,881.000 1,2,3,4 MT Rosebud Rosebud RR 0.610 8.490 8,604 N/A N/A N/A N/A N/A

RBMCOB243 13,802.000 1,2,3,4 MT Rosebud Rosebud RR 0.520 8.120 8,790 N/A N/A N/A N/A N/A

RBMCOB244 14,641.000 1,2,3,4 MT Rosebud Rosebud RR 0.670 8.700 8,791 N/A N/A N/A N/A N/A

RBMCOB233 300.000 1,2,3,4 MT Rosebud Rosebud RR 0.620 8.360 8,887 N/A N/A N/A N/A N/A

RBMCOB245 13,321.000 1,2,3,4 MT Rosebud Rosebud RR 0.870 9.710 8,667 N/A N/A N/A N/A N/A

RBMCOB246 13,686.000 1,2,3,4 MT Rosebud Rosebud RR 0.870 9.860 8,738 N/A N/A N/A N/A N/A

RBMCOB247 13,801.000 1,2,3,4 MT Rosebud Rosebud RR 0.830 10.720 8,698 N/A N/A N/A N/A N/A

RBMCOB248 13,924.000 1,2,3,4 MT Rosebud Rosebud RR 0.780 10.530 8,619 N/A N/A N/A N/A N/A

RBMCOB249 13,801.000 1,2,3,4 MT Rosebud Rosebud RR 0.520 9.670 8,722 N/A N/A N/A N/A N/A

RBMCOB250 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.830 10.090 8,687 N/A N/A N/A N/A N/A

RBMCOB251 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.770 9.360 8,768 N/A N/A N/A N/A N/A

RBMCOB252 13,802.000 1,2,3,4 MT Rosebud Rosebud RR 0.860 10.340 8,595 N/A N/A N/A N/A N/A

RBMCOB253 13,801.000 1,2,3,4 MT Rosebud Rosebud RR 0.810 10.190 8,720 N/A N/A N/A N/A N/A

RBMCOB254 13,801.000 1,2,3,4 MT Rosebud Rosebud RR 0.770 10.080 8,683 N/A N/A N/A N/A N/A

RBMCOB255 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.730 9.370 8,780 N/A N/A N/A N/A N/A

RBMCOB256 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.690 9.090 8,745 N/A N/A N/A N/A N/A

RBMCOB257 14,160.000 1,2,3,4 MT Rosebud Rosebud RR 0.650 9.010 8,858 N/A N/A N/A N/A N/A

RBMCOB258 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.670 9.040 8,926 N/A N/A N/A N/A N/A

RBMCOB259 13,809.000 1,2,3,4 MT Rosebud Rosebud RR 0.700 9.770 8,683 N/A N/A N/A N/A N/A

RBMCOB260 13,801.000 1,2,3,4 MT Rosebud Rosebud RR 0.740 9.420 8,747 N/A N/A N/A N/A N/A

RBMCOB261 13,801.000 1,2,3,4 MT Rosebud Rosebud RR 0.660 9.280 8,866 N/A N/A N/A N/A N/A

RBMCOB262 13,801.000 1,2,3,4 MT Rosebud Rosebud RR 0.660 9.030 8,665 N/A N/A N/A N/A N/A

RBMCOB263 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.710 9.510 8,923 N/A N/A N/A N/A N/A

RBMCOB264 13,801.000 1,2,3,4 MT Rosebud Rosebud RR 0.660 8.720 8,814 N/A N/A N/A N/A N/A

RBMCOB265 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.670 9.210 8,828 N/A N/A N/A N/A N/A

RBMCOB266 13,921.000 1,2,3,4 MT Rosebud Rosebud RR 0.710 9.500 8,793 N/A N/A N/A N/A N/A

RBMCOB267 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.640 9.220 8,780 N/A N/A N/A N/A N/A

RBMCOB268 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.610 8.830 8,650 N/A N/A N/A N/A N/A

RBMCOB269 13,681.000 1,2,3,4 MT Rosebud Rosebud RR 0.630 8.850 8,662 N/A N/A N/A N/A N/A

RBMCOB270 13,802.000 1,2,3,4 MT Rosebud Rosebud RR 0.700 9.610 8,707 N/A N/A N/A N/A N/A

RBMCOB271 13,920.000 1,2,3,4 MT Rosebud Rosebud RR 0.630 8.750 8,709 N/A N/A N/A N/A N/A

RBMCOB272 13,921.000 1,2,3,4 MT Rosebud Rosebud RR 0.770 9.820 8,611 N/A N/A N/A N/A N/A

RBMCOB273 14,044.000 1,2,3,4 MT Rosebud Rosebud RR 0.550 9.190 8,632 N/A N/A N/A N/A N/A

RBMCOB274 13,920.000 1,2,3,4 MT Rosebud Rosebud RR 0.660 8.750 8,791 N/A N/A N/A N/A N/A

RBMCOB275 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.640 9.210 8,746 N/A N/A N/A N/A N/A

RBMCOB276 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.660 9.350 8,715 N/A N/A N/A N/A N/A

RBMCOB277 13,802.000 1,2,3,4 MT Rosebud Rosebud RR 0.600 9.730 8,646 N/A N/A N/A N/A N/A

RBMCOB278 13,560.000 1,2,3,4 MT Rosebud Rosebud RR 0.740 9.250 8,818 N/A N/A N/A N/A N/A

RBMCOB279 13,802.000 1,2,3,4 MT Rosebud Rosebud RR 0.590 8.420 8,898 N/A N/A N/A N/A N/A

RBMCOB280 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.650 9.240 8,896 N/A N/A N/A N/A N/A
RBMCOB281 13,803.000 1,2,3,4 MT Rosebud Rosebud RR 0.620 9.150 8,883 N/A N/A N/A N/A N/A

RBMCOB282 14,161.000 1,2,3,4 MT Rosebud Rosebud RR 0.630 8.930 8,564 N/A N/A N/A N/A N/A

RBMCOB283 13,801.000 1,2,3,4 MT Rosebud Rosebud RR 0.680 9.780 8,655 N/A N/A N/A N/A N/A

RBMCOB284 14,043.000 1,2,3,4 MT Rosebud Rosebud RR 0.690 8.500 8,602 N/A N/A N/A N/A N/A

RBMCOB285 14,280.000 1,2,3,4 MT Rosebud Rosebud RR 0.650 9.690 8,586 N/A N/A N/A N/A N/A

RBMCOB286 14,040.000 1,2,3,4 MT Rosebud Rosebud RR 0.670 9.740 8,540 N/A N/A N/A N/A N/A

RBMCOB287 13,561.000 1,2,3,4 MT Rosebud Rosebud RR 0.700 10.210 8,428 N/A N/A N/A N/A N/A

RBMCOB288 14,160.000 1,2,3,4 MT Rosebud Rosebud RR 0.600 10.130 8,457 N/A N/A N/A N/A N/A

RBMCOB289 13,801.000 1,2,3,4 MT Rosebud Rosebud RR 0.590 10.140 8,641 N/A N/A N/A N/A N/A

RBMCOB290 13,801.000 1,2,3,4 MT Rosebud Rosebud RR 0.540 9.070 8,644 N/A N/A N/A N/A N/A

RBMCOB291 13,681.000 1,2,3,4 MT Rosebud Rosebud RR 0.600 9.000 8,763 N/A N/A N/A N/A N/A

RBMCOB292 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.540 9.020 8,726 N/A N/A N/A N/A N/A

RBMCOB293 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.710 9.820 8,554 N/A N/A N/A N/A N/A

RBMCOB294 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.590 8.920 8,674 N/A N/A N/A N/A N/A

RBMCOB295 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.600 9.190 8,631 N/A N/A N/A N/A N/A

RBMCOB296 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.600 8.910 8,753 N/A N/A N/A N/A N/A

RBMCOB297 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.640 10.370 8,417 N/A N/A N/A N/A N/A

RBMCOB298 13,802.000 1,2,3,4 MT Rosebud Rosebud RR 0.580 9.070 8,634 N/A N/A N/A N/A N/A

RBMCOB299 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.550 8.810 8,791 N/A N/A N/A N/A N/A

RBMCOB200 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.590 9.660 8,585 N/A N/A N/A N/A N/A

RBMCOB201 13,691.000 1,2,3,4 MT Rosebud Rosebud RR 0.550 9.710 8,597 N/A N/A N/A N/A N/A

RBMCOB202 13,803.000 1,2,3,4 MT Rosebud Rosebud RR 0.560 8.990 8,764 N/A N/A N/A N/A N/A

RBMCOB203 13,681.000 1,2,3,4 MT Rosebud Rosebud RR 0.620 9.790 8,558 N/A N/A N/A N/A N/A

RBMCOB204 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.550 9.340 8,497 N/A N/A N/A N/A N/A

RBMCOB205 13,607.000 1,2,3,4 MT Rosebud Rosebud RR 0.630 8.220 8,684 N/A N/A N/A N/A N/A

RBMCOB206 12,842.000 1,2,3,4 MT Rosebud Rosebud RR 0.680 8.590 8,675 N/A N/A N/A N/A N/A

RBMCOB207 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.560 8.840 8,732 N/A N/A N/A N/A N/A

RBMCOB208 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.610 8.850 8,710 N/A N/A N/A N/A N/A

RBMCOB209 13,800.000 1,2,3,4 MT Rosebud Rosebud RR 0.600 8.950 8,660 N/A N/A N/A N/A N/A

DKMCOB301 13,323.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.350 4.680 9,370 N/A N/A N/A N/A N/A

DKMCOB302 13,283.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.380 4.330 9,402 N/A N/A N/A N/A N/A

DKMCOB303 13,887.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.400 4.510 9,360 N/A N/A N/A N/A N/A

DKMCOB304 13,754.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.470 5.920 9,220 N/A N/A N/A N/A N/A

DKMCOB305 13,625.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.540 4.670 9,488 N/A N/A N/A N/A N/A

DKMCOB306 13,830.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.450 3.740 9,741 N/A N/A N/A N/A N/A

DKMCOB307 13,614.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.450 5.050 9,377 N/A N/A N/A N/A N/A

DKMCOB308 13,170.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.470 3.780 9,590 N/A N/A N/A N/A N/A

DKMCOB309 13,852.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.450 5.570 9,344 N/A N/A N/A N/A N/A

DKMCOB310 13,825.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.490 5.180 9,419 N/A N/A N/A N/A N/A

DKMCOB311 13,133.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.430 4.390 9,643 N/A N/A N/A N/A N/A

DKMCOB312 13,944.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.480 4.210 9,624 N/A N/A N/A N/A N/A

DKMCOB313 13,770.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.450 4.080 9,715 N/A N/A N/A N/A N/A

DKMCOB314 13,183.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.460 4.230 9,655 N/A N/A N/A N/A N/A
DKMCOB315 13,865.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.350 4.040 9,398 N/A N/A N/A N/A N/A

DKMCOB316 13,861.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.400 4.920 9,280 N/A N/A N/A N/A N/A

DKMCOB317 13,868.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.420 4.950 9,225 N/A N/A N/A N/A N/A

DKMCOB318 13,849.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.440 5.070 9,281 N/A N/A N/A N/A N/A

DKMCOB319 13,859.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.350 4.330 9,368 N/A N/A N/A N/A N/A

DKMCOB320 13,738.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.380 4.690 9,342 N/A N/A N/A N/A N/A

DKMCOB321 14,754.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.260 4.290 9,266 N/A N/A N/A N/A N/A

DKMCOB322 13,819.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.320 4.640 9,249 N/A N/A N/A N/A N/A

DKMCOB323 14,470.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.410 4.520 9,323 N/A N/A N/A N/A N/A

DKMCOB324 14,701.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.450 4.370 9,454 N/A N/A N/A N/A N/A

DKMCOB325 13,859.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.370 5.210 9,301 N/A N/A N/A N/A N/A

DKMCOB326 14,236.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.520 4.380 9,533 N/A N/A N/A N/A N/A

DKMCOB327 13,860.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.370 4.600 9,480 N/A N/A N/A N/A N/A

DKMCOB328 14,128.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.380 4.190 9,473 N/A N/A N/A N/A N/A

DKMCOB329 13,858.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.380 4.920 9,381 N/A N/A N/A N/A N/A

DKMCOB330 13,855.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.390 5.050 9,334 N/A N/A N/A N/A N/A

DKMCOB331 13,978.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.370 4.420 9,375 N/A N/A N/A N/A N/A

DKMCOB332 13,859.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.390 4.350 9,439 N/A N/A N/A N/A N/A

DKMCOB333 13,879.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.440 4.880 9,468 N/A N/A N/A N/A N/A

DKMCOB334 13,869.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.430 4.530 9,528 N/A N/A N/A N/A N/A

DKMCOB335 13,858.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.410 4.840 9,465 N/A N/A N/A N/A N/A

DKMCOB336 13,858.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.440 5.240 9,282 N/A N/A N/A N/A N/A

DKMCOB337 13,871.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.440 4.530 9,408 N/A N/A N/A N/A N/A

DKMCOB338 15,182.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.370 4.880 9,241 N/A N/A N/A N/A N/A

DKMCOB339 13,858.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.370 4.450 9,500 N/A N/A N/A N/A N/A

DKMCOB340 13,869.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.450 3.970 9,649 N/A N/A N/A N/A N/A

DKMCOB341 13,853.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.450 4.440 9,566 N/A N/A N/A N/A N/A

DKMCOB342 14,219.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.390 4.460 9,456 N/A N/A N/A N/A N/A

DKMCOB343 13,868.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.390 4.280 9,545 N/A N/A N/A N/A N/A

DKMCOB344 14,587.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.480 4.180 9,568 N/A N/A N/A N/A N/A

DKMCOB345 13,860.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.500 4.720 9,444 N/A N/A N/A N/A N/A

DKMCOB346 13,845.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.450 3.880 9,631 N/A N/A N/A N/A N/A

DKMCOB347 13,864.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.430 5.130 9,362 N/A N/A N/A N/A N/A

DKMCOB348 13,850.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.380 6.000 9,249 N/A N/A N/A N/A N/A

DKMCOB349 13,856.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.460 4.220 9,559 N/A N/A N/A N/A N/A

DKMCOB350 13,858.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.560 5.240 9,422 N/A N/A N/A N/A N/A

DKMCOB351 13,858.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.520 5.480 9,451 N/A N/A N/A N/A N/A

DKMCOB352 13,839.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.520 5.290 9,418 N/A N/A N/A N/A N/A

DKMCOB353 13,865.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.440 4.570 9,509 N/A N/A N/A N/A N/A

DKMCOB354 13,881.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.370 4.320 9,499 N/A N/A N/A N/A N/A

DKMCOB356 14,819.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.320 4.050 9,507 N/A N/A N/A N/A N/A

DKMCOB355 13,858.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.450 4.280 9,414 N/A N/A N/A N/A N/A

DKMCOB357 14,535.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.460 4.340 9,444 N/A N/A N/A N/A N/A
DKMCOB358 13,855.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.410 4.220 9,383 N/A N/A N/A N/A N/A

DKMCOB359 14,539.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.400 4.140 9,389 N/A N/A N/A N/A N/A

DKMCOB360 13,869.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.440 4.290 9,419 N/A N/A N/A N/A N/A

DKMCOB361 14,223.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.320 3.840 9,423 N/A N/A N/A N/A N/A

DKMCOB362 13,858.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.400 4.180 9,423 N/A N/A N/A N/A N/A

DKMCOB363 13,870.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.380 3.990 9,488 N/A N/A N/A N/A N/A

DKMCOB364 13,866.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.510 4.070 9,436 N/A N/A N/A N/A N/A

DKMCOB365 13,862.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.370 3.930 9,386 N/A N/A N/A N/A N/A

DKMCOB366 13,896.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.340 3.830 9,413 N/A N/A N/A N/A N/A

DKMCOB367 13,860.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.470 5.070 9,361 N/A N/A N/A N/A N/A

DKMCOB368 13,760.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.350 4.340 9,359 N/A N/A N/A N/A N/A

DKMCOB369 13,873.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.340 4.770 9,604 N/A N/A N/A N/A N/A

DKMCOB370 13,957.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.300 4.850 9,519 N/A N/A N/A N/A N/A

DKMCOB371 13,738.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.320 4.400 9,740 N/A N/A N/A N/A N/A

DKMCOB372 13,978.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.350 5.010 9,630 N/A N/A N/A N/A N/A

DKMCOB373 13,625.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.360 4.960 9,633 N/A N/A N/A N/A N/A

DKMCOB374 13,851.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.380 5.670 9,554 N/A N/A N/A N/A N/A

DKMCOB375 13,746.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.400 4.610 9,673 N/A N/A N/A N/A N/A

DKMCOB376 13,499.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.470 4.250 9,766 N/A N/A N/A N/A N/A

DKMCOB377 13,736.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.430 4.520 9,592 N/A N/A N/A N/A N/A

DKMCOB378 13,377.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.490 4.260 9,626 N/A N/A N/A N/A N/A

DKMCOB379 14,007.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.460 4.150 9,541 N/A N/A N/A N/A N/A

DKMCOB380 13,152.000 1,2,3,4 MT Big Horn Dietz 1 and Dietz 2 RR 0.440 4.290 9,569 N/A N/A N/A N/A N/A

SCMCOB601 13,024.175 1,2,3,4 MT Big Horn Anderson Dietz RR 0.400 4.150 9,373 N/A N/A N/A N/A N/A

SCMCOB602 13,123.775 1,2,3,4 MT Big Horn Anderson Dietz RR 0.320 4.370 9,352 N/A N/A N/A N/A N/A

SCMCOB603 13,152.575 1,2,3,4 MT Big Horn Anderson Dietz RR 0.360 4.140 9,278 N/A N/A N/A N/A N/A

SCMCOB604 12,907.250 1,2,3,4 MT Big Horn Anderson Dietz RR 0.360 4.200 9,465 N/A N/A N/A N/A N/A

SCMCOB605 11,211.825 1,2,3,4 MT Big Horn Anderson Dietz RR 0.310 5.270 9,172 N/A N/A N/A N/A N/A

SCMCOB606 12,467.525 1,2,3,4 MT Big Horn Anderson Dietz RR 0.320 3.860 9,364 N/A N/A N/A N/A N/A

SCMCOB607 11,713.000 1,2,3,4 MT Big Horn Anderson Dietz RR 0.290 4.040 9,320 N/A N/A N/A N/A N/A

SCMCOB608 13,835.800 1,2,3,4 MT Big Horn Anderson Dietz RR 0.280 3.880 9,436 N/A N/A N/A N/A N/A

SCMCOB609 13,943.500 1,2,3,4 MT Big Horn Anderson Dietz RR 0.290 4.030 9,266 N/A N/A N/A N/A N/A

SCMCOB610 14,829.850 1,2,3,4 MT Big Horn Anderson Dietz RR 0.280 4.460 9,432 N/A N/A N/A N/A N/A

SCMCOB611 12,912.650 1,2,3,4 MT Big Horn Anderson Dietz RR 0.290 4.050 9,438 N/A N/A N/A N/A N/A

SCMCOB612 14,139.450 1,2,3,4 MT Big Horn Anderson Dietz RR 0.280 4.230 9,297 N/A N/A N/A N/A N/A

SCMCOB613 13,666.000 1,2,3,4 MT Big Horn Anderson Dietz RR 0.280 4.450 9,329 N/A N/A N/A N/A N/A

SCMCOB614 14,057.975 1,2,3,4 MT Big Horn Anderson Dietz RR 0.270 4.410 9,427 N/A N/A N/A N/A N/A

SCMCOB615 14,776.700 1,2,3,4 MT Big Horn Anderson Dietz RR 0.290 3.810 9,497 N/A N/A N/A N/A N/A

SCMCOB616 13,825.100 1,2,3,4 MT Big Horn Anderson Dietz RR 0.290 5.500 9,300 N/A N/A N/A N/A N/A

SCMCOB617 12,413.575 1,2,3,4 MT Big Horn Anderson Dietz RR 0.300 4.180 9,367 N/A N/A N/A N/A N/A

SCMCOB618 13,880.325 1,2,3,4 MT Big Horn Anderson Dietz RR 0.340 4.340 9,387 N/A N/A N/A N/A N/A

SCMCOB619 13,626.125 1,2,3,4 MT Big Horn Anderson Dietz RR 0.310 4.360 9,389 N/A N/A N/A N/A N/A

SCMCOB620 13,995.050 1,2,3,4 MT Big Horn Anderson Dietz RR 0.320 4.620 9,404 N/A N/A N/A N/A N/A
SCMCOB621 13,938.900 1,2,3,4 MT Big Horn Anderson Dietz RR 0.310 4.210 9,382 N/A N/A N/A N/A N/A

SCMCOB622 13,505.450 1,2,3,4 MT Big Horn Anderson Dietz RR 0.330 4.280 9,389 N/A N/A N/A N/A N/A

SCMCOB623 13,921.750 1,2,3,4 MT Big Horn Anderson Dietz RR 0.310 4.070 9,494 N/A N/A N/A N/A N/A

SCMCOB624 14,039.200 1,2,3,4 MT Big Horn Anderson Dietz RR 0.370 5.300 9,280 N/A N/A N/A N/A N/A

SCMCOB625 13,566.750 1,2,3,4 MT Big Horn Anderson Dietz RR 0.390 4.930 9,287 N/A N/A N/A N/A N/A

SCMCOB626 13,944.425 1,2,3,4 MT Big Horn Anderson Dietz RR 0.350 4.250 9,305 N/A N/A N/A N/A N/A

SCMCOB627 13,953.625 1,2,3,4 MT Big Horn Anderson Dietz RR 0.360 4.920 9,194 N/A N/A N/A N/A N/A

SCMCOB628 14,673.550 1,2,3,4 MT Big Horn Anderson Dietz RR 0.420 4.190 9,350 N/A N/A N/A N/A N/A

SCMCOB629 13,959.050 1,2,3,4 MT Big Horn Anderson Dietz RR 0.350 4.470 9,308 N/A N/A N/A N/A N/A

SCMCOB630 13,907.500 1,2,3,4 MT Big Horn Anderson Dietz RR 0.350 4.410 9,252 N/A N/A N/A N/A N/A

SCMCOB631 14,017.625 1,2,3,4 MT Big Horn Anderson Dietz RR 0.340 4.300 9,319 N/A N/A N/A N/A N/A

SCMCOB632 13,870.325 1,2,3,4 MT Big Horn Anderson Dietz RR 0.410 4.970 9,161 N/A N/A N/A N/A N/A

SCMCOB633 14,903.575 1,2,3,4 MT Big Horn Anderson Dietz RR 0.410 4.730 9,318 N/A N/A N/A N/A N/A

SCMCOB634 14,310.500 1,2,3,4 MT Big Horn Anderson Dietz RR 0.340 5.140 9,191 N/A N/A N/A N/A N/A

SCMCOB635 14,104.000 1,2,3,4 MT Big Horn Anderson Dietz RR 0.250 3.840 9,464 N/A N/A N/A N/A N/A

SCMCOB636 13,992.875 1,2,3,4 MT Big Horn Anderson Dietz RR 0.290 4.030 9,502 N/A N/A N/A N/A N/A

SCMCOB637 13,988.625 1,2,3,4 MT Big Horn Anderson Dietz RR 0.290 4.170 9,419 N/A N/A N/A N/A N/A

SCMCOB638 13,878.450 1,2,3,4 MT Big Horn Anderson Dietz RR 0.330 4.860 9,237 N/A N/A N/A N/A N/A

SCMCOB639 14,048.875 1,2,3,4 MT Big Horn Anderson Dietz RR 0.290 3.800 9,440 N/A N/A N/A N/A N/A

SCMCOB640 14,896.500 1,2,3,4 MT Big Horn Anderson Dietz RR 0.330 4.500 9,334 N/A N/A N/A N/A N/A

SCMCOB641 14,851.150 1,2,3,4 MT Big Horn Anderson Dietz RR 0.330 4.080 9,246 N/A N/A N/A N/A N/A

SCMCOB642 14,902.325 1,2,3,4 MT Big Horn Anderson Dietz RR 0.460 5.360 9,144 N/A N/A N/A N/A N/A

SCMCOB643 14,121.400 1,2,3,4 MT Big Horn Anderson Dietz RR 0.350 4.110 9,357 N/A N/A N/A N/A N/A

SCMCOB644 13,961.625 1,2,3,4 MT Big Horn Anderson Dietz RR 0.370 4.140 9,361 N/A N/A N/A N/A N/A

SCMCOB645 14,911.325 1,2,3,4 MT Big Horn Anderson Dietz RR 0.290 4.620 9,270 N/A N/A N/A N/A N/A

SCMCOB646 14,075.250 1,2,3,4 MT Big Horn Anderson Dietz RR 0.290 3.930 9,369 N/A N/A N/A N/A N/A

SCMCOB647 14,935.300 1,2,3,4 MT Big Horn Anderson Dietz RR 0.320 4.650 9,226 N/A N/A N/A N/A N/A

SCMCOB648 14,972.200 1,2,3,4 MT Big Horn Anderson Dietz RR 0.350 4.240 9,423 N/A N/A N/A N/A N/A

SCMCOB649 13,864.250 1,2,3,4 MT Big Horn Anderson Dietz RR 0.360 4.730 9,205 N/A N/A N/A N/A N/A

SCMCOB650 13,997.450 1,2,3,4 MT Big Horn Anderson Dietz RR 0.310 3.930 9,422 N/A N/A N/A N/A N/A

SCMCOB651 14,560.300 1,2,3,4 MT Big Horn Anderson Dietz RR 0.340 4.380 9,254 N/A N/A N/A N/A N/A

SCMCOB652 13,973.775 1,2,3,4 MT Big Horn Anderson Dietz RR 0.330 3.890 9,334 N/A N/A N/A N/A N/A

SCMCOB653 13,994.275 1,2,3,4 MT Big Horn Anderson Dietz RR 0.340 4.040 9,393 N/A N/A N/A N/A N/A

SCMCOB654 13,701.975 1,2,3,4 MT Big Horn Anderson Dietz RR 0.280 3.930 9,408 N/A N/A N/A N/A N/A

SCMCOB655 14,271.950 1,2,3,4 MT Big Horn Anderson Dietz RR 0.330 4.580 9,174 N/A N/A N/A N/A N/A

SCMCOB656 13,958.625 1,2,3,4 MT Big Horn Anderson Dietz RR 0.350 4.700 9,277 N/A N/A N/A N/A N/A

SCMCOB657 13,253.875 1,2,3,4 MT Big Horn Anderson Dietz RR 0.340 4.110 9,324 N/A N/A N/A N/A N/A

SCMCOB658 13,961.275 1,2,3,4 MT Big Horn Anderson Dietz RR 0.320 4.040 9,351 N/A N/A N/A N/A N/A

SCMCOB659 13,969.900 1,2,3,4 MT Big Horn Anderson Dietz RR 0.330 4.230 9,417 N/A N/A N/A N/A N/A

SCMCOB660 14,312.000 1,2,3,4 MT Big Horn Anderson Dietz RR 0.320 4.020 9,348 N/A N/A N/A N/A N/A

SCMCOB661 13,951.525 1,2,3,4 MT Big Horn Anderson Dietz RR 0.370 4.370 9,325 N/A N/A N/A N/A N/A

SCMCOB662 13,740.325 1,2,3,4 MT Big Horn Anderson Dietz RR 0.370 4.830 9,185 N/A N/A N/A N/A N/A

SCMCOB663 13,974.100 1,2,3,4 MT Big Horn Anderson Dietz RR 0.290 4.390 9,188 N/A N/A N/A N/A N/A
SCMCOB664 14,598.150 1,2,3,4 MT Big Horn Anderson Dietz RR 0.340 4.400 9,235 N/A N/A N/A N/A N/A

SCMCOB665 13,986.375 1,2,3,4 MT Big Horn Anderson Dietz RR 0.460 5.000 9,022 N/A N/A N/A N/A N/A

SCMCOB666 14,281.400 1,2,3,4 MT Big Horn Anderson Dietz RR 0.270 5.570 9,178 N/A N/A N/A N/A N/A

SCMCOB667 14,005.700 1,2,3,4 MT Big Horn Anderson Dietz RR 0.390 4.990 9,237 N/A N/A N/A N/A N/A

SCMCOB668 14,208.275 1,2,3,4 MT Big Horn Anderson Dietz RR 0.350 5.080 9,259 N/A N/A N/A N/A N/A

SCMCOB669 14,965.225 1,2,3,4 MT Big Horn Anderson Dietz RR 0.430 4.710 9,318 N/A N/A N/A N/A N/A

SCMCOB670 14,105.800 1,2,3,4 MT Big Horn Anderson Dietz RR 0.330 4.290 9,369 N/A N/A N/A N/A N/A

SCMCOB671 13,968.675 1,2,3,4 MT Big Horn Anderson Dietz RR 0.390 5.240 9,351 N/A N/A N/A N/A N/A

SCMCOB672 13,992.650 1,2,3,4 MT Big Horn Anderson Dietz RR 0.490 4.640 9,331 N/A N/A N/A N/A N/A

SCMCOB673 13,876.200 1,2,3,4 MT Big Horn Anderson Dietz RR 0.400 4.360 9,464 N/A N/A N/A N/A N/A

SCMCOB674 13,900.000 1,2,3,4 MT Big Horn Anderson Dietz RR 0.450 4.500 9,397 N/A N/A N/A N/A N/A

TRAXCOB101 236.080 1,2,3,4 MT Big Horn Anderson Dietz RR 0.460 5.030 9,214 N/A N/A N/A N/A N/A

BTMCOB101 13,980.250 1,2,3,4 WY Campbell N/A RR 0.340 5.130 8,936 N/A N/A N/A N/A N/A

BTMCOB102 13,503.300 1,2,3,4 WY Campbell N/A RR 0.340 5.280 8,765 N/A N/A N/A N/A N/A

BTMCOB103 13,972.700 1,2,3,4 WY Campbell N/A RR 0.300 5.020 8,844 N/A N/A N/A N/A N/A

BTMCOB104 13,988.650 1,2,3,4 WY Campbell N/A RR 0.240 4.810 8,910 N/A N/A N/A N/A N/A

BTMCOB105 13,997.100 1,2,3,4 WY Campbell N/A RR 0.370 5.340 8,903 N/A N/A N/A N/A N/A

CAMCOB101 13,949.000 1,2,3,4 WY Campbell N/A RR 0.300 5.000 8,503 N/A N/A N/A N/A N/A

CAMCOB102 13,891.000 1,2,3,4 WY Campbell N/A RR 0.320 4.900 8,606 N/A N/A N/A N/A N/A

CAMCOB103 13,940.000 1,2,3,4 WY Campbell N/A RR 0.300 4.800 8,656 N/A N/A N/A N/A N/A

CAMCOB104 13,934.000 1,2,3,4 WY Campbell N/A RR 0.360 5.400 8,513 N/A N/A N/A N/A N/A

CAMCOB105 14,001.000 1,2,3,4 WY Campbell N/A RR 0.360 5.300 8,486 N/A N/A N/A N/A N/A

CAMCOB106 13,970.000 1,2,3,4 WY Campbell N/A RR 0.310 5.200 8,518 N/A N/A N/A N/A N/A

CAMCOB107 13,978.000 1,2,3,4 WY Campbell N/A RR 0.340 4.800 8,622 N/A N/A N/A N/A N/A

ATMCOB101 12,987.225 1,2,3,4 WY Converse N/A RR 0.240 5.720 8,755 N/A N/A N/A N/A N/A

ATMCOB102 13,743.825 1,2,3,4 WY Converse N/A RR 0.260 5.100 8,802 N/A N/A N/A N/A N/A

ATMCOB103 13,983.775 1,2,3,4 WY Converse N/A RR 0.290 4.660 8,963 N/A N/A N/A N/A N/A

ATMCOB104 13,948.175 1,2,3,4 WY Converse N/A RR 0.330 4.980 8,953 N/A N/A N/A N/A N/A

Oil Shipments - Boswell Energy Center

OMB 2060-063 Part II Questions 2-3

ID Gallons Boiler ID# State County Coal Seam

Fuel Ship 

Method Sulfur Ash Btu/Lb Mercury Chlorine Fluorine Nickel Other

COMO01621 7,513.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO01706 7,513.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO105827 7,494.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO105840 7,200.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO105936 7,505.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO105956 7,200.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO106982 7,499.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A
COMO107086 7,299.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO107092 7,517.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO109050 7,503.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO109051 7,503.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO109054 7,504.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO109135 7,200.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO109136 7,197.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO109146 7,711.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO109234 7,501.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO109256 7,201.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO109264 7,601.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO110290 7,302.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO110302 7,703.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO110424 7,300.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO110432 7,600.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO111015 7,304.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO111019 7,600.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO111062 7,502.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO111064 7,508.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO111752 7,104.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO111763 7,102.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO111769 7,303.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO111830 7,101.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO111842 7,301.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO112951 7,297.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO112952 7,507.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO114511 7,202.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO114528 7,505.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO114593 7,500.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO114601 7,508.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO114707 7,201.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO114723 7,502.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO114847 7,199.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO114862 7,506.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO114980 7,200.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO116624 7,502.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO116635 7,503.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO116752 7,202.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO116762 7,500.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO118562 7,500.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO118583 7,503.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO118732 7,300.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO118752 7,504.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A
COMO118924 7,303.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO118947 7,500.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO120036 7,503.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO120047 7,509.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO120208 7,300.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO120221 7,500.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO122347 7,202.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO122507 7,514.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO122569 7,199.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO122580 7,502.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO122723 7,197.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO122729 7,505.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO122858 7,299.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO122863 7,500.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO125740 7,201.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO125753 7,505.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO125917 7,206.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO125932 7,503.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO128103 7,202.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO128120 7,502.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO130398 7,300.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO130403 7,502.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO130534 7,202.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO130542 7,502.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO655869 300.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO95290 7,513.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO95349 7,513.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO95878 7,514.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO95904 7,514.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO95923 7,505.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

COMO96898 7,505.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A

EDW94211 7,200.00 1,2,3,4 MN N/A N/A TR 0.200 0.100 137,000 N/A N/A N/A N/A N/A
OMB 2060-0631 Part I, Question 8a, 8b, 8f

Minnesota Power Boswell Energy Center (1893)

Boiler ID

(as listed in Part I question 

15)

Question 8a 

Emission test report, 

parametric monitoring data, 

or other data or monitoring

Question 8b

Date of testing

Question 8b

Type of testing

Question 8b

Constituents

Question 8f

Did the unit's control 

configuration differ for 

that shown in Part I, 

questions 16 at the time 

of the test? Boiler ID Type

NOx 

Control

SO2 

Control PM Control

Other 

Control

Boiler 1 and Boiler 2 GE Energy

Mercury Engineering Study

3/28-29/2006 stack mercury yes B1 & B2 LNB none Baghouse none

Boiler 1, Boiler 2, Boiler 3 and 

Boiler 4

GE Energy

PM & PM10 Testing

5/22-24/2007 stack PM & PM10 yes B3

B4

none

none

none

FGD

Wet Scr

Boiler 1 and Boiler 2 Platt Environmental Services, 

Inc

Mercury Testing

6/24/2008 stack mercury yes B1 & B2 LNB none Baghouse none

Boiler 4 Alstom

Mercury Testing

5/19/2022 stack mercury no

Boiler 1 and Boiler 2 GE Energy

PM & PM10 Testing

7/22-24/2009 stack PM & PM10 no

Boiler 3 GE Energy

SCR Inlet and Outlet

1/6-8/2010 Emission study H2SO4

, NH4, NOx and SO2 no

Boiler 3 GE Energy

PM Engineering Study

2/11/2010 Baghouse Outlet PM no
OMB 2060-0631 Part II, Question 12

Minnesota Power Boswell Energy Center (1893)Boiler ID Test Date PM* SO2 HCL/HF/HCN Metal HAP Hg* CO* Other organic

Unit Load (MW)

Net MWH NET)

Moisture(%) Flow

(dscfm 

Boiler 1 and Boiler 2 3/28-29/2006 Unit 1 total Hg = 0.00169 lb/hr

 2.82E-6 lb/mmBtu particle = 0.0 lb/hr 0.00E-6 lb/mmBtu oxidized = 0.00144 lb/hr 2.39E-6 lb/mmBtu elemental = 0.00026 

Unit 1 = 69.5Unit 2 = 52.4

Unit 1 = 12.0Unit 2 = 11.2

Unit 1 = Unit 2 = 

Boiler 1, Boiler 2, Boiler 3 and Boiler 4

5/22-24/2007 Unit 1 & 2 filterable PM = 0.01 lb/mmBtu

 total PM10 =0.08 lb/mmBtuUnit 3 filterable PM = 0.13 lb/mmBtu total PM10 =0.13 lb/mmBtuUnit 4 filterable PM10 = 0.06 lb/mmBtu total PM =0.07 lb/mmBtu

Unit 1 & 2 = 140.7Unit 3 = 353Unit 4 = 356

Unit 1 & 2 = 10.3 Unit 3 = 12.4Unit 4 = 14.3

Unit 1 & Unit 3 = Unit 4 = 

Boiler 1 and Boiler 2 6/24/2008Boiler 4 5/19/2022 Mercury control testing at econimizer 

outlet and stack

Boiler 1 and Boiler 2 7/22-24/2009 No UREA filterable PM = 0.01 lb/mmBtu

 condensible PM = 0.20 lb/mmBtuUREA on filterable PM = 0.01 lb/mmBtu condensible PM = 0.19 lb/mmBtu

No UREA = 137.8UREA on = 138.0

No UREA = 10.5UREA on = 11.1

No UREUREA o

Boiler 3 1/6-8/2010 SCR inlet = 0.80 ppm

SCR outlet = 11.40 ppm

NH4 SCR outlet 

= 0.04 ppmNH4 SCR outlet = 27.50 ug/dscmNOx SCR inlet = 

103.22 ppmvdNOx SCR outlet 

= 19.87 ppmvd

Boiler 3 2/11/2010 Unit 3 PM concentration filterable = 0.0019 

gr/dscfUnit 3 PM concentration aqueous condensible = 0.0013 gr/dscfUnit 3 PM concentration organic condensible = 0.0021 gr/dscfUnit 3 PM concentration total = 0.0053 gr/dscfUnit 3 PM emission rate filterable = 12.97 lb/hrUnit 3 PM emission rate aqueous condensible = 8.91 lb/hrUnit 3 PM emission rate organic condensible = 13.90 lb/hrUnit 3 PM emission rate total = 35.79 lb/hrUnit 3 PM emission rate filterable = 0.0038 lb/mmBtuUnit 3 PM emission rate aqueous condensible = 0.0026 lb/mmBtuUnit 3 PM emission rate organic condensible = 0.0041 lb/mmBtuUnit 3 PM emission rate total = 0.0105 lb/mmBtu

 9.7 781,327 

* Averaging Time = 3 - 1 hour rounds

TDD (for hearing and speech impaired only): (651) 282-5332 

Printed on recycled paper containing at least 10% fibers from paper recycled by consumers 

AIR EMISSION PERMIT NO. 13700015 - 004 

Administrative Amendment 

IS ISSUED TO

Minnesota Power Division of Allete Inc 

Minnesota Power Inc - Hibbard Renewable Energy Center 

4913 Main Street 

Duluth, St. Louis County, MN 55807 

The emission units, control equipment and emission stacks at the stationary source authorized in this 

permit amendment are as described below in the Permit Applications Table. 

This permit amendment supersedes Air Emission Permit No. 13700015-003 and authorizes the Permittee 

to operate the stationary source at the address listed above unless otherwise noted in Table A. The 

Permittee must comply with all the conditions of the permit. Any changes or modifications to the 

stationary source must be performed in compliance with Minn. R. 7007.1150 to 7007.1500. Terms used 

in the permit are as defined in the state air pollution control rules unless the term is explicitly defined in 

the permit. 

Unless otherwise indicated, all the Minnesota rules cited as the origin of the permit terms are incorporated 

into the State Implementation Plant under 40 CFR § 52.1220 and as such are enforceable by U.S. 

Environmental Protection Agency (EPA) Administrator or citizens under the Clean Air Act. 

Permit Type: Federal; Pt 70/Major for NSR

Operating Permit Issue Date: August 15, 2006

Administrative Amendment Issue Date: December 23, 2009

Expiration Date: August 15, 2011 – Title I Conditions do not expire.

 

 Don Smith, P.E., Manager 

 Air Quality Permits Section 

 Industrial Division 

 

for Paul Eger 

Commissioner 

 Minnesota Pollution Control Agency 

Permit Applications Table

Permit Type Application Date Permit Action 

Total Facility Operating Permit - Reissuance January 14, 2002 003 

Administrative Amendment 

August 18, 2008, with 

supplemental information 

submitted October 5, 2009 

004 

TABLE OF CONTENTS 

Notice to the Permittee 

Permit Shield 

Facility Description 

Amendment Description

Table A: Limits and Other Requirements 

Table B: Submittals 

Appendices 

Appendix I – Insignificant Activities 

Appendix II – Phase II Permit Application (federal Acid Rain regulations) 

NOTICE TO THE PERMITTEE: 

Your stationary source may be subject to the requirements of the Minnesota Pollution Control Agency’s 

(MPCA) solid waste, hazardous waste, and water quality programs. If you wish to obtain information on 

these programs, including information on obtaining any required permits, please contact the MPCA 

general information number at: 

 Metro Area 651-296-6300 

 

 Outside Metro Area 1-800-657-3864 

 TTY 651-282-5332 

The rules governing these programs are contained in Minn. R. chs. 7000-7105. Written questions may be 

sent to: Minnesota Pollution Control Agency, 520 Lafayette Road North, St. Paul, Minnesota 55155-4194. 

Questions about this air emission permit or about air quality requirements can also be directed to the 

telephone numbers and address listed above. 

PERMIT SHIELD:

Subject to the limitations in Minn. R. 7007.1800, compliance with the conditions of this permit shall be 

deemed compliance with the specific provision of the applicable requirement identified in the permit as 

the basis of each condition. Subject to the limitations of Minn. R. 7007.1800 and 7017.0100, subp. 2, 

notwithstanding the conditions of this permit specifying compliance practices for applicable requirements, 

any person (including the Permittee) may also use other credible evidence to establish compliance or 

noncompliance with applicable requirements. 
FACILITY DESCRIPTION: 

Permit Action 003 - Reissuance 

The Hibbard Renewable Energy Center (Facility) steam and power generating facility was jointly owned 

by Minnesota Power (MP) and the City of Duluth. Boilers 3 & 4 and their associated equipment were 

owned by the City of Duluth, whereas MP owned the remaining portion of the facility. The facility is 

located in the City of Duluth, adjacent to the NewPage paper mill. The facility combusts a mixture of 

wood, coal, natural gas and paper mill sludge. The primary mission of the facility is to produce steam for 

NewPage Duluth Paper Mill and its associated paper recycling facility. The facility is also capable of 

producing electrical energy for the MP system. The site contains four steam generating boilers, four steam 

turbines, coal handling facilities, wood handling facilities, a 3.4 million gallon fuel oil storage tank and 

natural gas supply lines. The two oldest boilers and their associated turbine-generators (Boilers No. 1 and 

No. 2), and the fuel oil supply tank have been out of service since 1981, but can be used if future plans 

were to change. 

All operations and equipment within the facility boundary are established to: (1) provide steam and/or 

electrical power for on-site and off-site utilization; (2) provide fuel for steam and/or electrical power 

production or support activities; (3) monitor and control air emissions generated from electrical power 

production; (4) handle waste heat, wastes and materials produced from the on-site operations; and (5) 

provide support activities. The description of these operations and equipment are described below. 

Steam and Power Generation

Steam and power generation is accomplished primarily through steam generation in two boilers (Boilers 

No. 3 and No. 4). Both units have spreader stokers and traveling grates. Emissions are discharged through 

a common 331 foot stack (Stack No. 1). Boilers No. 1 and No. 2 are smaller units and if used would also 

discharge air emissions through Stack No. 1. 

Fuel for Steam and Power Generation and Support Equipment/Activities

Boilers No. 3 and No. 4 are capable of combusting a mixture of wood, sub-bituminous coal, natural gas 

and sludge. The primary fuel is wood, which may include wood chips, sawdust, sanderdust, wood bark, 

chipped railroad ties and other various forms of waste wood from regional suppliers. The wood fuel is 

supplemented with low-sulfur, sub-bituminous coal and natural gas. Boilers No. 3 and No. 4 are capable 

of combusting wood, coal, and various combinations of wood, coal, and natural gas. This permit allows 

for the addition of oily coal (coal with oil spilled on it), oily cellulose-based sorbents (including rags), 

activated charcoal, boiler cleaning agents, and cellulose fill from mattress recycling as permitted fuels. 

The wood fuel is delivered directly to the plant in covered trucks, unloaded and conveyed directly to the 

A-frame storage building. The wood fuel is conveyed to the wood metering bins and transferred to the 

boiler’s traveling grate through the auger feed and spreader stoker systems. Combustion occurs in 

suspension and on the grate. 

Coal is delivered to the facility in trucks and unloaded in a three sided enclosure maintained at negative 

pressure and vented through a fabric filter. Coal is transferred from the unloading facility to storage 

bunkers by a bucket conveyor system. Air from the bunkers and coal transfer system is vented through a 

fabric filter. Coal transfer from the bunker to the boilers is accomplished by a totally enclosed conveyor. 

Natural gas is supplied to Boilers No. 3 and No. 4 through a pipeline. Natural gas could be supplied to 

Boilers No. 1 and No. 2 by the same system. 

If used in the future as fuel, oil would be delivered by truck and stored in the 3.4 million gallon tank. 

Piping, which would connect the fuel oil storage to the boilers is currently disconnected. 
Air Emission Monitoring and Control

Air emissions from the facility are released primarily as a result of the combustion of wood and coal. 

Smaller amounts of criteria pollutants are emitted from the combustion of natural gas and the handling 

and storage of coal and wood fuels. The combustion of wood and coal also results in the emission of some 

hazardous air emissions. 

Continuous Emission Monitors have been installed, tested and certified to measure and record the 

combustion emissions from Boilers No. 3 and No. 4 exiting via the common stack, Stack No. 1. The 

monitors measure and record information on the following parameters: Sulfur Dioxide, Nitrogen Oxides, 

opacity, Carbon Monoxide, Carbon Dioxide, and volumetric flow and are located in the breaching leading 

to the stack. 

Particulate emissions from Stack No. 1 due to combustion in Boilers No. 3 and No. 4 are controlled by 

multiple cyclones in series with an electrostatic precipitator for each unit. Boilers No. 1 and No. 2 do not have 

associated pollution control equipment. Particulates from coal unloading, transfer, and storage are controlled 

with fabric filter baghouses. Additional particulate control is accomplished through the use of enclosures to 

limit fugitive emissions from coal and wood unloading operations. 

Waste Heat, Wastes, and Materials 

The facility is designed to operate with a once-through cooling system to dissipate waste heat in the 

production of electrical energy. Water from St. Louis Bay is pumped through the intake structure, used to 

condense steam from the back side of the turbine generator and discharged to the bay. 

The combustion of wood and coal also produces ash, which is collected off the traveling grates, wetted and 

transferred to a truck. The ash is used as agricultural soil enhancement or is landfilled. 

Support Activities

Support activities include the building elevator, vehicle maintenance, general facility activities, energy 

production equipment maintenance, piping installation and maintenance. These activities can include 

painting, welding, and cleaning operations. In terms of air emission regulations, these activities are 

considered insignificant activities for these purposes. 

AMENDMENT DESCRIPTION: 

Permit Action 004 – Administrative Administration

This administrative amendment is for a change in ownership. Minnesota Power has purchased the City of 

Duluth’s portion of the Facility and now has sole ownership of the Facility. 

TABLE A: LIMITS AND OTHER REQUIREMENTS 12/23/09

Minnesota Power Inc - Hibbard Renewable Energy Ctr

13700015 - 004

Facility Name:

Permit Number:

A-1

Table A contains limits and other requirements with which your facility must comply. The limits are located in the first column of

the table (What To do). The limits can be emission limits or operational limits. This column also contains the actions that you must

take and the records you must keep to show that you are complying with the limits. The second column of Table A (Why to do it)

lists the regulatory basis for these limits. Appendices included as conditions of your permit are listed in Table A under total facility

requirements.

Subject Item: Total Facility

What to do Why to do it

SOURCE-SPECIFIC REQUIREMENTS hdr

Permit Appendices: This permit contains 2 appendices as listed in the permit Table

of Contents. The Permittee shall comply with all requirements contained in the

appendices.

Minn. R. 7007.0800, subp. 2

Comply with the Fugitive Control Plan: The Permittee shall follow the actions and

recordkeeping specified in the control plan. The plan may be amended by the

Permittee with the Commissioner's approval. If the Commissioner determines the

Permittee is out of compliance with Minn R. 7011.0150 or the fugitive control plan,

then the Permittee may be required to amend the control plan and/or to install and

operate particulate matter ambient monitors as requested by the Commissioner.

Minn. Stat. Section 116.07, subd. 4a; Minn. R.

7007.0100; Minn. R. 7007.0800, subp. 2; Minn. R.

7011.0150; Minn. R. 7009.0020.

DETERMINING IF A PROJECT/MODIFICATION IS SUBJECT TO NEW SOURCE

REVIEW

hdr

These requirements apply where there is a reasonable possibility that a proposed

project, analyzed using the actual-to-projected-actual (ATPA) test and found to not

be part of a major modification, may result in a significant emissions increase. If

the ATPA test is not used for a particular project, or if there is not a reasonable

possibility that the proposed project could result in a significant emissions increase,

then these requirements do not apply to that project.

Even though a particular modification is not subject to New Source Review, a

permit amendment, recordkeeping, or notification may still be required under Minn.

R. 7007.1150 - 7007.1500.

Title I Condition: 40 CFR Section 52.21(r)(6) and Minn.

R. 7007.3000

Preconstruction Documentation -- Before beginning actual construction on a

project, the Permittee shall document the following information:

1. A description of the project

2. Identification of the emission unit(s) whose emissions of an NSR pollutant could

be affected

3. A description of the applicability test used to determine that the project is not a

major modification for any regulated NSR pollutant, including the baseline actual

emissions, the potential emissions, the projected actual emissions, the amount of

emissions excluded due to increases not associated with the modification and that

the unit(s) could have accommodated during the baseline period, an explanation of

why the amounts were excluded, and any creditable contemporaneous increases

and decreases that were considered in the determination.

The Permittee shall maintain records of this documentation.

Title I Condition: 40 CFR Section 52.21(r)(6) and Minn.

R. 7007.3000; Minn. R. 7007.0800, subp. 4 & 5

The Permittee shall monitor the actual emissions of any regulated NSR pollutant

that could increase as a result of the project and that were analyzed using the

ATPA test, and the potential emissions of any regulated NSR pollutant that could

increase as a result of the project and that were analyzed using potential

emissions. The Permittee shall calculate and maintain a record of the sum of the

actual and potential (if used in the analysis) emissions of the regulated pollutant, in

tons per year on a calendar year basis, for a period of 5 years following resumption

of regular operations after the change, or for a period of 10 years following

resumption of regular operations after the change if the project increases the

design capacity of or potential to emit of any unit associated with the project.

Title I Condition: 40 CFR Section 52.21(r)(6) and Minn.

R. 7007.3000; Minn. R. 7007.0800, subp. 4 & 5

Before beginning actual construction of any project which includes any electric

utility steam generating unit (EUSGU), the Permittee shall submit a copy of the

preconstruction documentation (items 1-3 under Preconstruction Documentation,

above) to the Agency.

Title I Condition: 40 CFR Section 52.21(r)(6)(ii) and

Minn. R. 7007.3000; Minn. R. 7007.0800, subp. 4 & 5
TABLE A: LIMITS AND OTHER REQUIREMENTS 12/23/09

Minnesota Power Inc - Hibbard Renewable Energy Ctr

13700015 - 004

Facility Name:

Permit Number:

A-2

For any project which includes any EUSGU, the Permittee must submit an annual

report to the Agency, within 60 days after the end of the calendar year. The report

shall contain:

a. The name and ID number of the facility, and the name and telephone number of

the facility contact person

b. The quantified annual emissions analyzed using the ATPA test, plus the

potential emissions associated with the same project and analyzed using potential

emissions

c. Any other information, such as an explanation as to why the summed emissions

differ from the preconstruction projection, if that is the case.

Title I Condition: 40 CFR Section 52.21(r)(6) and Minn.

R. 7007.3000; Minn. R. 7007.0800, subp. 4 & 5

For any project which does not include any EUSGU, the Permittee must submit a

report to the Agency if the annual summed (actual plus potential, if applicable)

emissions differ from the preconstruction projection and exceed the baseline actual

emissions by a significant amount as listed at 40 CFR Section 52.21(b)(23). Such

report shall be submitted to the Agency within 60 days after the end of the year in

which the exceedances occur. The report shall contain:

a. The name and ID number of the facility, and the name and telephone number of

the facility contact person

b. The annual emissions (actual plus potential, if any part of the project was

analyzed using potential emissions) for each pollutant for which the preconstruction

projection and significant emissions rate is exceeded.

c. Any other information, such as an explanation as to why the summed emissions

differ from the preconstruction projection.

Title I Condition: 40 CFR Section 52.21(r)(6) and Minn.

R. 7007.3000; Minn. R. 7007.0800, subp. 4 & 5

OPERATIONAL REQUIREMENTS hdr

The Permittee shall comply and upon written request demonstrate compliance, with

National Primary and Secondary Ambient Air Quality Standards, 40 CFR pt. 50,

and the Minnesota Ambient Air Quality Standards, Minn. R. 7009.0010 to

7009.0080.

40 CFR pt. 50; Minn. Stat. Section 116.07, subds. 4a &

9; Minn. R. 7007.0100, supbs. 7A, 7L & 7M; Minn. R.

7007.0800, subps. 1, 2 & 4; Minn. R.

7009.0100-7009.0080.

Circumvention: Do not install or use a device or means that conceals or dilutes

emissions, which would otherwise violate a federal or state air pollution control rule,

without reducing the total amount of pollutant emitted.

Minn. R. 7011.0020

Air Pollution Control Equipment: Operate all pollution control equipment whenever

the corresponding process equipment and emission units are operated, unless

otherwise noted in Table A.

Minn. R. 7007.0800, subp. 2; Minn. R. 7007.0800,

supb. 16(J)

Operation and Maintenance Plan: Retain at the stationary source an operation and

maintenance plan for all air pollution control equipment. At a minimum, the O & M

plan shall identify all air pollution control equipment and control practices and shall

include a preventative maintenance program for the equipment and practices, a

description of (the minimum but not necessarily the only) corrective actions to be

taken to restore the equipment and practices to proper operation to meet applicable

permit conditions, a description of the employee training program for proper

operation and maintenance of the control equipment and practices, and the records

kept to demonstrate plan implementation.

Minn. R. 7007.0800, subp. 14 & subp. 16(J)

Operation Changes: In any shutdown, breakdown, or deviation the Permittee shall

immediately take all practical steps to modify operations to reduce the emission of

any regulated air pollutant. The Commissioner may require feasible and practical

modifications in the operation to reduce emissions of air pollutants. No emissions

units that have an unreasonable shutdown or breakdown frequency of process or

control equipment shall be permitted to operate.

Minn. R. 7019.1000, subp. 4

Fugitive Emissions: Do not cause or permit the handling, use, transporting, or

storage of any material in a manner which may allow avoidable amounts of

particulate matter to become airborne. Comply with all other requirements listed in

Minn. R. 7011.0150.

Minn. R. 7011.0150

Noise: The Permittee shall comply with the noise standards set forth in Minn. R.

7030.0010 to 7030.0080 at all times during the operation of any emission units.

This is a state only requirement and is not federally enforceable.

Minn. R. 7030.0010-7030.0080

Inspections: Upon presentation of credentials and other documents as may be

required by law, allow the Agency, or its representative, to enter the Permittee's

premises, to have access to and copy any records required by this permit, to

inspect at reasonable times (which include any time the source is operating) any

facilities, equipment, practices or operations, and to sample or monitor any

substances or parameters at any location. The Permittee may require that MPCA

inspectors be accompanied by MP staff during the inspection. Permittee's staff

shall be available whenever the plant is operating.

Minn. R. 7007.0800, subp. 9(A)

The Permittee shall comply with the General Conditions listed in Minn. R.

7007.0800, subp. 16.

Minn. R. 7007.0800, subp. 16
TABLE A: LIMITS AND OTHER REQUIREMENTS 12/23/09

Minnesota Power Inc - Hibbard Renewable Energy Ctr

13700015 - 004

Facility Name:

Permit Number:

A-3

Coal handling: not to exceed 241,200 tons on a 12-month rolling sum. Coal

handling operations limited to 8 hours per day.

Title I Conditions: PSD total facility permit application &

impacts and

Minn. R. 7007.3000

Wet all ash and cover ash haul trucks leaving the facility. Minn. R. 7007.0800, subp. 2

Cover all wood hauling systems except for unloading. Minn. R. 7007.0800, subp. 2

Access areas, roads, parking facilities

All paved roads and areas shall be cleaned to minimize the discharge to the

atmosphere of fugitive particulate emissions. Such cleaning shall be accomplished

in a manner which minimizes resuspension of particulate matter. Access areas

surrounding coal stockpiles and parking facilities which are located within a coal

handling facility shall be treated with water or chemical agents.

Minn. R. 7011.1105

Truck and hauler unloading stations: Control fugitive particulate emissions from the

unloading of trucks or haulers by dust suppression methods so that emissions from

such sources are minimized.

Minn. R. 7011.1105

Enclosed coal handling facilites or emissions units not specifically covered by any

other provision in these parts. If exhaust gases from any enclosed coal handling

facility exceed 20 percent opacity, then the owner or operator of such facility shall

select and implement one of the following further controls:

 (1) install exhaust air system and control exhaust gases so that particulate

emissions in such gases do not exceed 0.020 gr/dscf;

 (2) control exhaust gases using dust suppression methods so that particulate

emissions do not exhibit greater than 20 percent opacity.

Minn. R. 7011.1105

Operating practices: Clean up all coal spilled on roads or access areas as soon as

practicable using methods that minimize the amount of dust suspended.

Maintain air pollution control equipment in proper operating condition and utilize air

pollution control systems as designed.

Minn. R. 7011.1105

For all baghouses controlling emissions from enclosed coal handling equipment

including those listed an insignificant activity:

 1. Inspect quarterly, or as required by manufacturing specifications, all

components that are not subject to wear or plugging, including structural

components, housing, ducts, and hoods. Maintain a written record of the inspection

and any action resulting from the inspection.

 2. Inspect monthly, or as required by manufacturing specifications, all

components that are subject to wear or plugging. Maintain a written record of the

inspection and any action resulting from the inspection.

 3. Check visible emissions once every 48 hours. If visible emissions exist,

inspect equipment for evidence of malfunction, including broken bags. Record the

results of the inspection, and any action taken.

Minn. R. 7011.1105

Oily Floor Dry: Limit combustion to (for entire facility): 1) cellulose based only

(including rags), 2) 25 tons per year, and 3) 1.25 tons per hour.

Title I Condition: to ensure that the emissions increase

from the addition of the fuel type is less than significant

as defined by 40 CFR Section 52.21;

Minn. R. 7007.3000

Activated Charcoal: Limit combustion to (for entire facility): 1) material generated on

site, material received from Newpage Duluth Paper Mill, or material received from

other off-site facilities that is representative of the same material, 2) 25 tons per

year, and 3) 3 tons per hour.

Title I Condition: to ensure that the emissions increase

from the addition of the fuel type is less than significant

as defined by 40 CFR Section 52.21;

Minn. R. 7007.3000

PERFORMANCE TESTING hdr

Performance Testing: Conduct all performance tests in accordance with Minn. R.

ch. 7017 unless otherwise noted in Tables A, B, and/or C.

Minn. R. ch. 7017

Performance Test Notifications and Submittals:

Performance Tests are due as outlined in Tables A and B of the permit. See Table

B for additional testing requirements.

Performance Test Notification (written): due 30 days before each Performance Test

Performance Test Plan: due 30 days before each Performance Test

Performance Test Pre-test Meeting: due 7 days before each Performance Test

Performance Test Report: due 45 days after each Performance Test

Performance Test Report - CD or Microfiche Copy: due 105 days after each

Performance Test

The Notification, Test Plan, and Test Report may be submitted in alternative format

as allowed by Minn. R. 7017.2018.

Minn. Rs. 7017.2030, subp. 1-4, 7017.2018 and Minn.

R. 7017.2035, subp. 1-2
TABLE A: LIMITS AND OTHER REQUIREMENTS 12/23/09

Minnesota Power Inc - Hibbard Renewable Energy Ctr

13700015 - 004

Facility Name:

Permit Number:

A-4

Operating and/or production limits will be placed on emission units based on

operating conditions during compliance testing. Limits set as a result of a

compliance test (conducted before or after permit issuance) apply until new

operating/production limits are set following formal review of a performance test as

specified by Minn. R. 7017.2025.

Minn. R. 7017.2025

MONITORING REQUIREMENTS hdr

Operation of Monitoring Equipment: Unless otherwise noted in Tables A, B, and/or

C, monitoring a process or control equipment connected to that process is not

necessary during periods when the process is shutdown, such as for system

breakdowns, repairs, calibration checks, and zero and span adjustments (as

applicable). Monitoring records should reflect any such periods of process

shutdown.

Minn. R. 7007.0800, subp. 4(D)

Monitoring Equipment Calibration: Annually calibrate all required monitoring

equipment (any requirements applying to continuous emission monitors are listed

separately in this permit).

Minn. R. 7007.0800, subp. 4(D)

RECORDKEEPING hdr

Record keeping: Retain all records at the stationary source for a period of five (5)

years from the date of monitoring, sample, measurement, or report. Records which

must be retained at this location include all calibration and maintenance records, all

original strip-chart recordings for continuous monitoring instrumentation, fuel

analyses and certifications, and copies of all reports required by the permit.

Records must conform to the requirements listed in Minn. R. 7007.0800, subp.

5(A).

Minn. R. 7007.0800, subp. 5(C)

Record keeping: Maintain records describing any insignificant modifications (as

required by Minn. R. 7007.1250, subp. 3) or changes contravening permit terms (as

required by Minn. R. 7007.1350, subp. 2), including records of the emissions

resulting from those changes.

Minn. R. 7007.0800, subp. 5(B)

If the Permittee determines that no permit amendment or notification is required

prior to making a change, the Permittee must retain records of all calculations

required under Minn. R. 7007.1200.For expiring permits, these records shall be

kept for a period of five years from the date the change was made or until permit

reissuance, whichever is longer. The records shall be kept at the stationary source

for the current calendar year of operation and may be kept at the stationary source

or office of the stationary source for all other years. The records may be maintained

in either electronic or paper format.

Minn. R. 7007.1200, subp. 4

Recordkeeping to demonstrate compliance with coal handling limit: By the 15th day

of each month, the Permittee shall calculate and record the total coal handled in

the previous month, and calculate and record the total coal handled during the

previous 12-month period.

Title I Conditions: PSD total facility permit application &

impacts analysis and

Minn. R. 7007.3000

REPORTING hdr

Shutdowns: Notify the Commissioner at least 24 hours in advance of shutdown of

any process or control equipment, if the shutdown would cause an increase in the

emission of air contaminants. At the time of notification, notify the Commissioner of

the cause of the shutdown and the estimated duration. Notify the Commissioner

again when the shutdown is over.

Minn. R. 7019.1000, subp. 1

Breakdowns: Notify the Commissioner immediately of a breakdown of more than

one hour duration of any process or control equipment, if the breakdown causes an

increase in the emission of air contaminants. At the time of notification or as soon

thereafter as possible, the Permittee shall also notify the Commissioner of the

cause of the breakdown and the estimated duration. Notify the Commissioner again

when the breakdown is over.

Shutdown and Breakdown Reporting Requirements for the Dust Collector Systems

for Material Handling Equipment: Shutdowns and breakdowns shall be reported on

a quarterly basis to the Agency. The quarterly report shall include an identification

of the dust collector that broke down or was shutdown, the time and reason for the

breakdown or shutdown, a description of any repairs made, and the date and time

the dust collector was placed back in service.

Minn. R. 7019.1000, subp. 2

Oral Notification of Deviations Endangering Human Health or the Environment:

Within 24 hours of discovery, orally notify the Commissioner of any deviation from

permit conditions which could endanger human health or the environment.

Minn. R. 7007.0800, subp. 6(A)

Discovery of Deviations Endangering Human Health or the Environment Report

(written): due two working days after discovery of deviation, submit a written

description of any deviation endangering human health or the environment to the

Commissioner. Include the following information in this written description: cause

of the deviation; exact dates of the period of the deviation; if the deviation has not

been corrected, the anticipated time it is expected to continue; and steps taken or

planned to reduce, eliminate, and prevent reoccurrence of the deviation.

Minn. R. 7007.0800, subp. 6(A)
TABLE A: LIMITS AND OTHER REQUIREMENTS 12/23/09

Minnesota Power Inc - Hibbard Renewable Energy Ctr

13700015 - 004

Facility Name:

Permit Number:

A-5

Application for Permit Amendment: If you need a permit amendment, submit

application in accordance with the requirements of Minn. R. 7007.1150 through

Minn. R. 7007.1500. Submittal dates vary, depending on the type of amendment

needed.

Minn. R. 7007.1150 through Minn. R. 7007.1500

For changes that do not require a permit amendment:

- The Permittee shall submit a Part 1 MACT application within 30 days of startup of

any 112(j) affected source. The application shall meet the requirements of 40 CFR

Section 63.53(a).

- The Permittee shall submit a Part 2 MACT application within 90 days of startup of

any 112(j) affected source. The application shall meet the requirements of 40 CFR

Section 63.53(b).

112(j) affected source is defined in 40 CFR Section 63.51. As of permit issuance,

112(j) affected sources include industrial, commercial, and institutional boilers and

process heaters; brick and structural clay products manufacturing; clay ceramics

manufacturing.

40 CFR Section 63.52(b)(1) and 63.52(e)(1)

Extension Requests: The Permittee may apply for an Administrative Amendment to

extend a deadline in a permit by no more than 120 days, provided the proposed

deadline extension meets the requirements of Minn. R. 7007.1400, subp. 1(H).

Minn. R. 7007.1400, subp. 1(H)

Emission Inventory Report: due on or before April 1 of each calendar year

following permit issuance. To be submitted on a form approved by the

Commissioner.

Minn. R. 7019.3000 through Minn. R. 7019.3010

Emission Fees: due 60 days after receipt of an MPCA bill Minn. R. 7002.0065
TABLE A: LIMITS AND OTHER REQUIREMENTS 12/23/09

Minnesota Power Inc - Hibbard Renewable Energy Ctr

13700015 - 004

Facility Name:

Permit Number:

A-6

Subject Item: GP 001 Boilers 3 and 4 

Associated Items: EU 003 Boiler 3 

EU 004 Boiler 4 

MR 101 SO2 monitor - low range

MR 102 NOx monitor

MR 103 CO2 monitor

MR 104 SO2 monitor - high range

MR 107 flow monitor

MR 108 opacity monitor

What to do Why to do it

TRIAL BURN REQUIREMENTS hdr

Waste wood fuel limit: The Permittee may burn up to 28,500 tons of woodwaste

consisting of rejects and/or trimmings consisting primarily of wood with some glues

and/or adhesives and backings. After 28,500 tons are burned, if the Permittee

wishes to continue burning waste wood as described herein, the Permittee shall

determine what permit amendment (if any) is necessary to continue as outlined

below.

Minn. 7007.0800, subp. 2

Notification/Reporting: The Permittee shall:

1) submit notification of the commencement of the trial burn, within 15 days of such

date;

2) submit notification of the completion of the trial burn, within 15 days of such date;

3) complete a report within 180 days of the completion of the trial burn that

examines the impact of burning waste wood as described herein on emissions

using records from the CEM/COM equipment at the facility and other information.

After the trial burn is complete, if the Permittee wishes to continue burning waste

wood as described herein a permit applicability determination should be made

using the information in the report required by # 3). If a permit amendment is

necessary, a copy of this report shall be included with the application.

Minn. 7007.0800, subps. 5 and 6
TABLE A: LIMITS AND OTHER REQUIREMENTS 12/23/09

Minnesota Power Inc - Hibbard Renewable Energy Ctr

13700015 - 004

Facility Name:

Permit Number:

A-7

Subject Item: EU 001 Boiler 1

Associated Items: SV 001 Main Stack

What to do Why to do it

EMISSION LIMITS hdr

Total Particulate Matter: less than or equal to 0.01 lbs/million BTU heat input based

on a 24-hour average

Title I Conditions: PSD Permit Application and impacts

analysis, 40 CFR Section 52.21(k); most stringent,

meets limit set by Minn. R. 7011.0510, subp. 1

Opacity: less than or equal to 20 percent opacity except up to 60% opacity for four

minutes in any 60-minute period and up to 40% opacity for four additional minutes

in any 60-minute period

Minn. R. 7011.0510, subp. 2

Sulfur Dioxide: less than or equal to 0.24 lbs/million BTU heat input on a one-hour

average

Title I Conditions: PSD Permit Application and impacts

analysis, 40 CFR Section 52.21(k), ; most stringent,

meets limit set by Minn. R. 7011.0510, subp. 1

Nitrogen Dioxide: less than or equal to 0.49 lbs/million BTU heat input on a 30-day

rolling average

Title I Conditions: PSD Permit Application and impacts

analysis, 40 CFR Section 52.21(k);

Minn. Rule 7007.3000

Carbon Monoxide: less than or equal to 0.04 lbs/million BTU heat input on a

one-hour average

Title I Conditions: PSD Permit Application and impacts

analysis, 40 CFR Section 52.21(k);

Minn. Rule 7007.3000

OPERATIONAL LIMITS hdr

Fuel limited to No. 2 Fuel oil only, except natural gas may be used as necessary for

initial firing only.

Title I Conditions: PSD Permit Application and impacts

analysis, 40 CFR Section 52.21(k);

Minn. Rule 7007.3000

No. 2 fuel oil shall have a minimum heating value of 136,598 Btu per gallon. Title I Conditions: PSD Permit Application and impacts

analysis, 40 CFR Section 52.21(k);

Minn. Rule 7007.3000

No. 2 fuel oil shall have a maximum ash content of 0.00141 lbs ash per gallon. Title I Conditions: PSD Permit Application and impacts

analysis, 40 CFR Section 52.21(k);

Minn. Rule 7007.3000

No. 2 fuel oil shall have a maximum sulfur content of 0.23% by weight. Title I Conditions: PSD Permit Application and impacts

analysis, 40 CFR Section 52.21(k);

Minn. Rule 7007.3000

MONITORING, RECORDKEEPING AND REPORTING HDR

The Permittee shall maintain records of No. 2 fuel oil sampling results or vendor

certifications, for a minimum of 5 years.

Title I Condition: PSD permit application and impacts

analysis, 40 CFR Section 52.21(k);

Minn. Rule 7007.3000

Collect and analyze a fuel oil sample from each delivery of fuel oil, or shall obtain

and keep copies of vendor certifications from each delivery. The information from

the vendor certification or analysis must give the fuel oil sulfur content, ash content,

and heating value for the purposes of demonstrating compliance with the sulfur

dioxide emission limit, the sulfur content limit, the ash content limit, and the

minimum heating value limit. All analyses shall be completed no later than 30 days

after the sampling date. Samples shall be collected from the fuel oil prior to the oil

being placed in the storage tank. The sample shall be analyzed for sulfur wt%,

heating value in Btu/lb, density in lb/gal, and ash content in wt%, following ASTM

methods D-1552, D-240, D-1481, and D-482, respectively, or equivalent methods

approved by the Commissioner.

Title I Condition: PSD permit application and impacts

analysis, 40 CFR Section 52.21(k);

Minn. Rule 7007.3000

Notify: due 30 days after Startup . Written notification of startup is required to

trigger the Initial Performance Test for Boiler No. 1.

Minn. R. 7007.0800, subp. 2

Initial Performance Test: due 180 days after Startup to determine compliance with

the particulate matter emission limit based on PSD modeling. Compliance shall be

determined based on the average of three runs per Minn. R. 7017.2020, subp. 5.

Minn. R. 7017.2020, subp. 1

Initial Performance Test: due 180 days after Startup to determine compliance with

the opacity limit based on PSD modeling. Compliance shall be determined based

on the average of three runs per Minn. R. 7017.2020, subp. 5.

Minn. R. 7017.2020, subp. 1

Initial Performance Test: due 180 days after Startup to determine compliance with

the nitrogen oxides emission limit based on PSD modeling. Compliance shall be

determined based on the average of three runs per Minn. R. 7017.2020, subp. 5.

Minn. R. 7017.2020, subp. 1

Initial Performance Test: due 180 days after Startup to determine compliance with

the carbon monoxide emission limit based on PSD modeling. Compliance shall be

determined based on the average of three runs per Minn. R. 7017.2020, subp. 5.

Minn. R. 7017.2020, subp. 1
TABLE A: LIMITS AND OTHER REQUIREMENTS 12/23/09

Minnesota Power Inc - Hibbard Renewable Energy Ctr

13700015 - 004

Facility Name:

Permit Number:

A-8

Performance Test Notifications and Submittals:

Performance Tests are due as outlined in Tables A and B of the permit. See Table

B for additional testing requirements.

Performance Test Notification (written): due 30 days before each Performance Test

Performance Test Plan: due 30 days before each Performance Test

Performance Test Pre-test Meeting: due 7 days before each Performance Test

Performance Test Report: due 45 days after each Performance Test

Performance Test Report - CD or Microfiche Copy: due 105 days after each

Performance Test

The Notification, Test Plan, and Test Report may be submitted in alternative format

as allowed by Minn. R. 7017.2018.

Minn. Rs. 7017.2030, subp. 1-4, 7017.2018 and Minn.

R. 7017.2035, subp. 1-2

Boiler Alternative Operating Conditions for Performance Testing:

Alternative Operating Conditions during testing are defined as 90% to 100% of the

boiler's maximum normal (continuous) operating load or the maximum permitted

operating rate, whichever is lower. The basis for this number must be included in

the test plan. If testing is conducted at the alternative operating condition

established, an operating limit will not be established as a result of performance

testing.

In no case will the new operating rate limit be higher than allowed by an existing

permit condition.

Minn. R. 7017.2025, subp. 2.A. and 3.B.

Boiler Operating Conditions Not Meeting the Alternative Operating Conditions

During Performance Testing:

If performance testing is not conducted at or above the established alternative

operating condition, then the boiler operating rate will be limited on an 8-hour block

average based on the following:

(1) If the results of the performance test are greater than 80% of any applicable

emission limit for which compliance is demonstrated, then boiler operation will be

limited to the tested operating rate.

(2) If results are less than or equal to 80% of all applicable emission limits for which

compliance is demonstrated, boiler operation will be limited to 110% of the tested

operating rate.

In no case will the new operating rate limit be higher than allowed by an existing

permit condition.

Minn. R. 7017.2025, subp. 3.B.

STET (Short Term Emergency and Testing) Operating hours limit:

The boiler may operate up to 40 hours per year to demonstrate the Uniform Rating

of Generating Equipment (URGE) capacity and to meet emergency energy supply

needs. Maintain documentation of all STET operation to demonstrate compliance

with this limit. The boiler must meet emission limits during STET operation.

Minn. R. 7007.0800, subp. 2

STET Operation Definition that applies to Boilers that Meet or do Not Meet the

Alternative Operating Condition for Performance Testing:

If performance test results demonstrate compliance at 80% or less of any

applicable emission limits for any tested pollutant, STET operation is defined as

operation beyond 110% of the average operating rate achieved during that

performance test.

If performance test results demonstrate compliance at greater than 80% any

applicable emision limit for any tested pollutant, STET operation is defined as

operation beyond 100% of the average operating rate achieved during that

performance test.

In no case will STET operation be higher than allowed by an existing permit

condition.

Minn. R. 7007.0800, subp. 2

The results of a performance test are not final until issuance of a review letter by

MPCA, unless specified otherwise by Minn. R. 7017.2001 - 7017.2060.

Minn. R. 7017.2020, subp. 4
TABLE A: LIMITS AND OTHER REQUIREMENTS 12/23/09

Minnesota Power Inc - Hibbard Renewable Energy Ctr

13700015 - 004

Facility Name:

Permit Number:

A-9

Subject Item: EU 002 Boiler 2

Associated Items: SV 001 Main Stack

What to do Why to do it

EMISSION LIMITS hdr

Total Particulate Matter: less than or equal to 0.01 lbs/million BTU heat input based

on a 24-hour average

Title I Conditions: PSD Permit Application and impacts

analysis, 40 CFR Section 52.21(k); most stringent,

meets limit set by Minn. R. 7011.0510, subp. 1

Opacity: less than or equal to 20 percent opacity except up to 60% opacity for four

minutes in any 60-minute period and up to 40% opacity for four additional minutes

in any 60-minute period

Minn. R. 7011.0510, subp. 2

Sulfur Dioxide: less than or equal to 0.24 lbs/million BTU heat input on a one-hour

average

Title I Conditions: PSD Permit Application and impacts

analysis, 40 CFR Section 52.21(k); most stringent,

meets limit set by Minn. R. 7011.0510, subp. 1

Nitrogen Dioxide: less than or equal to 0.49 lbs/million BTU heat input on a 30-day

rolling average

Title I Conditions: PSD Permit Application and impacts

analysis, 40 CFR Section 52.21(k);

Minn. Rule 7007.3000

Carbon Monoxide: less than or equal to 0.04 lbs/million BTU heat input on a

one-hour average

Title I Conditions: PSD Permit Application and impacts

analysis, 40 CFR Section 52.21(k);

Minn. Rule 7007.3000

OPERATIONAL LIMITS hdr

Fuel limited to No. 2 Fuel oil only, except natural gas may be used as necessary for

initial firing only.

Title I Conditions: PSD Permit Application and impacts

analysis, 40 CFR Section 52.21(k);

Minn. Rule 7007.3000

No. 2 fuel oil shall have a minimum heating value of 136,598 Btu per gallon. Title I Conditions: PSD Permit Application and impacts

analysis, 40 CFR Section 52.21(k);

Minn. Rule 7007.3000

No. 2 fuel oil shall have a maximum ash content of 0.00141 lbs ash per gallon. Title I Conditions: PSD Permit Application and impacts

analysis, 40 CFR Section 52.21(k);

Minn. Rule 7007.3000

No. 2 fuel oil shall have a maximum sulfur content of 0.23% by weight. Title I Conditions: PSD Permit Application and impacts

analysis, 40 CFR Section 52.21(k);

Minn. Rule 7007.3000

MONITORING, RECORDKEEPING AND REPORTING hdr

The Permittee shall maintain records of No. 2 fuel oil sampling results or vendor

certifications, for a minimum of 5 years.

Title I Condition: PSD permit application and impacts

analysis, 40 CFR Section 52.21(k);

Minn. Rule 7007.3000

Collect and analyze a fuel oil sample from each delivery of fuel oil, or shall obtain

and keep copies of vendor certifications from each delivery. The information from

the vendor certification or analysis must give the fuel oil sulfur content, ash content,

and heating value for the purposes of demonstrating compliance with the sulfur

dioxide emission limit, the sulfur content limit, the ash content limit, and the

minimum heating value limit. All analyses shall be completed no later than 30 days

after the sampling date. Samples shall be collected from the fuel oil prior to the oil

being placed in the storage tank. The sample shall be analyzed for sulfur wt%,

heating value in Btu/lb, density in lb/gal, and ash content in wt%, following ASTM

methods D-1552, D-240, D-1481, and D-482, respectively, or equivalent methods

approved by the Commissioner.

Title I Condition: PSD permit application and impacts

analysis, 40 CFR Section 52.21(k);

Minn. Rule 7007.3000

Notify: due 30 days after Startup . Written notification of startup is required to

trigger the Initial Performance Test for Boiler No. 2.

Minn. R. 7007.0800, subp. 2

Initial Performance Test: due 180 days after Startup to determine compliance with

the particulate matter emission limit based on PSD modeling. Compliance shall be

determined based on the average of three runs per Minn. R. 7017.2020, subp. 5.

Minn. R. 7017.2020, subp. 1

Initial Performance Test: due 180 days after Startup to determine compliance with

the opacity limit based on PSD modeling. Compliance shall be determined based

on the average of three runs per Minn. R. 7017.2020, subp. 5.

Minn. R. 7017.2020, subp. 1

Initial Performance Test: due 180 days after Startup to determine compliance with

the nitrogen oxides emission limit based on PSD modeling. Compliance shall be

determined based on the average of three runs per Minn. R. 7017.2020, subp. 5.

Minn. R. 7017.2020, subp. 1

Initial Performance Test: due 180 days after Startup to determine compliance with

the carbon monoxide emission limit based on PSD modeling. Compliance shall be

determined based on the average of three runs per Minn. R. 7017.2020, subp. 5.

Minn. R. 7017.2020, subp. 1
TABLE A: LIMITS AND OTHER REQUIREMENTS 12/23/09

Minnesota Power Inc - Hibbard Renewable Energy Ctr

13700015 - 004

Facility Name:

Permit Number:

A-10

Performance Test Notifications and Submittals:

Performance Tests are due as outlined in Tables A and B of the permit. See Table

B for additional testing requirements.

Performance Test Notification (written): due 30 days before each Performance Test

Performance Test Plan: due 30 days before each Performance Test

Performance Test Pre-test Meeting: due 7 days before each Performance Test

Performance Test Report: due 45 days after each Performance Test

Performance Test Report - CD or Microfiche Copy: due 105 days after each

Performance Test

The Notification, Test Plan, and Test Report may be submitted in alternative format

as allowed by Minn. R. 7017.2018.

Minn. Rs. 7017.2030, subp. 1-4, 7017.2018 and Minn.

R. 7017.2035, subp. 1-2

Boiler Alternative Operating Conditions for Performance Testing:

Alternative Operating Conditions during testing are defined as 90% to 100% of the

boiler's maximum normal (continuous) operating load or the maximum permitted

operating rate, whichever is lower. The basis for this number must be included in

the test plan. If testing is conducted at the alternative operating condition

established, an operating limit will not be established as a result of performance

testing.

In no case will the new operating rate limit be higher than allowed by an existing

permit condition.

Minn. R. 7017.2025, subp. 2.A. and 3.B.

Boiler Operating Conditions Not Meeting the Alternative Operating Conditions

During Performance Testing:

If performance testing is not conducted at or above the established alternative

operating condition, then the boiler operating rate will be limited on an 8-hour block

average based on the following:

(1) If the results of the performance test are greater than 80% of any applicable

emission limit for which compliance is demonstrated, then boiler operation will be

limited to the tested operating rate.

(2) If results are less than or equal to 80% of all applicable emission limits for which

compliance is demonstrated, boiler operation will be limited to 110% of the tested

operating rate.

In no case will the new operating rate limit be higher than allowed by an existing

permit condition.

Minn. R. 7017.2025, subp. 3.B.

STET (Short Term Emergency and Testing) Operating hours limit:

The boiler may operate up to 40 hours per year to demonstrate the Uniform Rating

of Generating Equipment (URGE) capacity and to meet emergency energy supply

needs. Maintain documentation of all STET operation to demonstrate compliance

with this limit. The boiler must meet emission limits during STET operation.

Minn. R. 7007.0800, subp. 2

STET Operation Definition that applies to Boilers that Meet or do Not Meet the

Alternative Operating Condition for Performance Testing:

If performance test results demonstrate compliance at 80% or less of any

applicable emission limits for any tested pollutant, STET operation is defined as

operation beyond 110% of the average operating rate achieved during that

performance test.

If performance test results demonstrate compliance at greater than 80% any

applicable emision limit for any tested pollutant, STET operation is defined as

operation beyond 100% of the average operating rate achieved during that

performance test.

In no case will STET operation be higher than allowed by an existing permit

condition.

Minn. R. 7007.0800, subp. 2

The results of a performance test are not final until issuance of a review letter by

MPCA, unless specified otherwise by Minn. R. 7017.2001 - 7017.2060.

Minn. R. 7017.2020, subp. 4
TABLE A: LIMITS AND OTHER REQUIREMENTS 12/23/09

Minnesota Power Inc - Hibbard Renewable Energy Ctr

13700015 - 004

Facility Name:

Permit Number:

A-11

Subject Item: EU 003 Boiler 3 

Associated Items: CE 001 Multiple Cyclone w/o Fly Ash Reinjection - Most Multiclones

CE 002 Electrostatic Precipitator - High Efficiency

GP 001 Boilers 3 and 4 

SV 001 Main Stack

What to do Why to do it

Total Particulate Matter: less than or equal to (0.025x + 0.027y)/(x+y) lb/mmBtu

based on a 24-hour average, where:

x = heat derived from the burning of coal over any hour in mmBtu

y = heat derived from the burning of wood and wood waste portion of sludge and

railroad ties over any hour in mmBtu

Title I Conditions: Limit to restrict potential emission

increases to less than significant as defined by 40 CFR

Section 51.165 and 40 CFR Section 52.24. Also

ensures compliance with 40 CFR Section 60.43b.

Minn. R. 7007.4000 - 7007.4030

Opacity: less than or equal to 20 percent opacity using 6 Minute Average except for

one 6-minute period per hour of not greater than 27% opacity.

40 CFR Section 60.43b(f)

Minn. R. 7011.0565

Nitrogen Oxides: less than or equal to (0.6x + 0.4y +0.1z)/(x+y+z) lb/mmBtu based

on a 30 day rolling average, where:

x = heat derived from the burning of coal over any hour in mmBtu

y = heat derived from the burning of wood and wood waste portion of sludge and

railroad ties over any hour in mmBtu

z = heat input from natural gas in mmBtu

Once each hour, the Permittee shall use the NOx emission limit equation to

calculate the effective NOx emission limit.

Title I Conditions: 40 CFR Section 52.21 BACT Limit;

40 CFR pt. 50. Also ensures compliance with 40 CFR

Section 60.44b.

Minn. R. 7007.3000

Carbon Monoxide: less than or equal to (0.35x + 0.45y + 0.04z)/(x+y+z) lb/mmBtu

based on a one-hour average, where:

x = heat derived from the burning of coal over any hour in mmBtu

y = heat derived from the burning of wood and wood waste portion of sludge and

railroad ties over any hour in mmBtu

z = heat input from natural gas in mmBtu

Title I Conditions: 40 CFR Section 52.21 BACT Limit;

40 CFR pt. 50

Minn. R. 7007.3000

Sulfur Dioxide: less than or equal to (2.03Sx + 0.17y)/(x+y) lb/mmBtu based on a

one hour averaging period, where:

S = the allowed sulfur content in coal in percent by weight determined by fuel

sampling and analysis (see the following requirement for more detail)

x = heat derived from the burning of coal over any hour in mmBtu

y = heat derived from the burning of wood and wood waste portion of sludge and

railroad ties over any hour in mmBtu

Once each hour, the Permittee shall use the SO2 emission limit equation to

calculate the effective SO2 emission limit.

Title I Conditions: 40 CFR Section 52.21 BACT Limit;

40 CFR pt. 50. Also ensures compliance with 40 CFR

Section 60.43(a)

Minn. R. 7007.3000

Limit of coal sulfur content (by weight):

 - 0.58% when burned alone or with natural gas or sludge,

 - may not exceed 0.9% at any time

 - When coal is being burned in combination with wood, the sulfur content limit

shall vary as follows:

 S = 8.13 X rE

 S = allowable percent sulfur by weight

 r = coal feed rate in tons per hour.

 E = the exponent (-0.88) of "r"

For use of this equation, r must be greater than or equal to 12. When r is less than

12, S = 0.9%.

Title I Conditions: PSD permit application and impacts

analysis

Minn. R. 7007.3000

The Permittee shall only burn wood (including creosoted railroad ties), coal, natural

gas, sludge from NewPage Duluth Paper Mill clarifier, oily cellulose-based sorbents

(including oily rags), oily coal and oily wood (coal or wood with oil spilled on it),

boiler cleaning agents, activated charcoal, hardboard rejects, and cellulose fill from

mattress recycling in EU003. Other materials may be combusted in this emission

unit for a short period of time during a trial burn as approved by an amendment to

this permit.

Title I Conditions: PSD permit application and impacts

analysis

Minn. R. 7007.3000
TABLE A: LIMITS AND OTHER REQUIREMENTS 12/23/09

Minnesota Power Inc - Hibbard Renewable Energy Ctr

13700015 - 004

Facility Name:

Permit Number:

A-12

Boiler cleaning agents burn requirements: agents must be EDTA type or

Ammonium Bromate, agents generated on-site, maximum of 5% of total fuel mass

input, oxygen must be 3% or greater, and agents may be burned only while the

boiler is operating at 75 percent of rated capacity or greater.

During the initial burn (after issuance of this permit) in EU 003 of boiler cleaning

agents, the Permittee shall monitor CO and opacity emissions to deterimine the

compliance status of CO and opacity emissions during the burn. Monitoring results

for the initial burn shall be submitted to the Agency. If compliance with the EU 003

CO and opacity limitations is shown, CO monitoring is not required during

subsequent boiler cleaning agent combustion events.

Minn. R. 7007.0800, subp. 2

Fuel usage limits:

 - 22 tons per hour for coal;

 - 67 tons per hour for wood;

 - 0.305 MMCF per hour for natural gas.

Title I Conditions: PSD permit application and impacts

analysis

Minn. R. 7007.3000

Fuel Sampling: The Permittee shall sample solid fuel as follows: 1) Daily

composite sampling for wood fuel; and 2) sample one coal delivery each week

according to the Permittee's sampling plans approved by the MPCA on November

18, 1987 (except the need for a duplicate gross 240 pound sample is not required).

Title I Conditions: PSD permit application and impacts

analysis

Minn. R. 7007.3000

Fuel Analysis: The Permittee shall analyze solid fuel samples using ASTM

methods or equivalent methods approved by the Commissioner. Samples shall be

analyzed for the following parameters:

Coal: Sulfur content in wt. %, heating value in Btus per lb.

Wood: Heating value in Btus per lb.

The average heating value for natural gas may be obtained from the vendor.

The Permittee shall maintain the records of all analyses for a period of 5 years from

the date of recording.

Title I Conditions: PSD permit application and impacts

analysis

Minn. R. 7007.3000

Maximum allowable heat input (based on 8-hour block averages):

 - 590 mmBtu/hour at any time

 - 380 mmBtu/hr from coal

 - 590 mmBtu/hr from wood

 - When wood fuel = 100% chipped railroad ties:

 maximum total heat input from all fuels = 326 mmBtu/hr,

 chipped railroad tie heat input shall not exceed 86% of total heat input, and

 coal heat input shall not be less than 14% of total heat input.

 - 305 mmBtu/hr from natural gas

Title I Conditions: PSD permit application and impacts

analysis

Minn. R. 7007.3000

Total heat input shall be determined using the following equations:

Total heat input to EU003 = x + y + z (not to exceed 590 mmBtu/hr)

 x = 380 - [(22-r) X (17.2)]

 y = 590 - [(67-s) X (8.8)]

 z = 305 - [(0.305-t) X (1000)]

x= heat derived from the burning of coal over any hour in mmBtu

y= heat derived from the burning of wood and wood waste portion of sludge and

railroad ties over any hour in mmBtu

z= heat derived from the burning of natural gas over any hour in mmBtu

r = coal feed rate to boiler in tons per hour

s = wood feed rate to boiler in tons per hour

t = natural gas feed rate to boiler in million cubic feet per hour

Title I Conditions: PSD permit application and impacts

analysis

Minn. R. 7007.3000

Monitoring and Recordkeeping for fuel usage and heat input:

The Permittee shall record the usage rate of each solid fuel on a daily basis, and

calculate and record the hourly average fuel use for each solid fuel by dividing the

daily fuel use by the number of hours of operation for that day. The Permittee shall

measure the natural gas usage rate, in million cubic feet per hour, using a fuel

meter.

The Permittee shall calculate and record the heat input during any hour from each

fuel, as well as the total heat input for that hour.

Heat content value of solid fuel shall be obtained from fuel sampling as required in

this permit. Heat content value of natural gas shall be obtained from the natural

gas vendor.

The Permittee shall maintain all fuel usage and heat input records for five years

from the date of recording.

Title I Conditions: PSD permit application and impacts

analysis

Minn. R. 7007.3000

Record type and usage rate of each fuel on a daily basis, and calculate the hourly

average fuel use for each fuel type by dividing the daily fuel use by the number of

hours of operation for that day. Records shall be maintained for a minimum of 5

years.

Title I Conditions: PSD permit application and impacts

analysis

Minn. R. 7007.3000
TABLE A: LIMITS AND OTHER REQUIREMENTS 12/23/09

Minnesota Power Inc - Hibbard Renewable Energy Ctr

13700015 - 004

Facility Name:

Permit Number:

A-13

Performance Test: due before end of each 60 months starting 04/01/2002 to

determine compliance with the Title I particulate matter emission limit while burning

coal, wood chips (including railroad ties), sludge, or any combination thereof. Tests

shall be conducted at intervals not to exceed 60 months between tests. Particulate

emissions testing shall be conducted in accordance with the procedures in 40 CFR

Section 60.46b(d) and Minn. R. 7017.2001 - 7017.2060 so that test results can also

be used to determine compliance with 40 CFR Section 60.43b.

Minn. R. 7017.2020, subp. 1

Performance Test: due before end of each 60 months following Initial Performance

Test to determine compliance with Title I CO emission limit while burning coal,

wood chips (including railroad ties), sludge, or any combination thereof. Tests shall

be conducted at intervals not to exceed 60 months between tests.

Minn. R. 7017.2020, subp. 1

Performance Test Notifications and Submittals:

Performance Tests are due as outlined in Tables A and B of the permit. See Table

B for additional testing requirements.

Performance Test Notification (written): due 30 days before each Performance Test

Performance Test Plan: due 30 days before each Performance Test

Performance Test Pre-test Meeting: due 7 days before each Performance Test

Performance Test Report: due 45 days after each Performance Test

Performance Test Report - CD or Microfiche Copy: due 105 days after each

Performance Test

The Notification, Test Plan, and Test Report may be submitted in alternative format

as allowed by Minn. R. 7017.2018.

Minn. Rs. 7017.2030, subp. 1-4, 7017.2018 and Minn.

R. 7017.2035, subp. 1-2

Boiler Alternative Operating Conditions for Performance Testing:

Alternative Operating Conditions during testing are defined as 90% to 100% of the

boiler's maximum normal (continuous) operating load or the maximum permitted

operating rate, whichever is lower. The basis for this number must be included in

the test plan. If testing is conducted at the alternative operating condition

established, an operating limit will not be established as a result of performance

testing.

In no case will the new operating rate limit be higher than allowed by an existing

permit condition.

Minn. R. 7017.2025, subp. 2(A) and 3(B)

Boiler Operating Conditions Not Meeting the Alternative Operating Conditions

During Performance Testing:

If performance testing is not conducted at or above the established alternative

operating condition, then the boiler operating rate will be limited on an 8-hour block

average based on the following:

(1) If the results of the performance test are greater than 80% of any applicable

emission limit for which compliance is demonstrated, then boiler operation will be

limited to the tested operating rate.

(2) If results are less than or equal to 80% of all applicable emission limits for which

compliance is demonstrated, boiler operation will be limited to 110% of the tested

operating rate.

In no case will the new operating rate limit be higher than allowed by an existing

permit condition.

Minn. R. 7017.2025, subp. 3(B)

STET (Short Term Emergency and Testing) Operating hours limit:

The boiler may operate up to 40 hours per year to demonstrate the Uniform Rating

of Generating Equipment (URGE) capacity and to meet emergency energy supply

needs. Maintain documentation of all STET operation to demonstrate compliance

with this limit. The boiler must meet emission limits during STET operation.

Minn. R. 7007.0800, subp. 2
TABLE A: LIMITS AND OTHER REQUIREMENTS 12/23/09

Minnesota Power Inc - Hibbard Renewable Energy Ctr

13700015 - 004

Facility Name:

Permit Number:

A-14

STET Operation Definition that applies to Boilers that Meet or do Not Meet the

Alternative Operating Condition for Performance Testing:

If performance test results demonstrate compliance at 80% or less of any

applicable emission limits for any tested pollutant, STET operation is defined as

operation beyond 110% of the average operating rate achieved during that

performance test.

If performance test results demonstrate compliance at greater than 80% any

applicable emision limit for any tested pollutant, STET operation is defined as

operation beyond 100% of the average operating rate achieved during that

performance test.

In no case will STET operation be higher than allowed by an existing permit

condition.

Minn. R. 7007.0800, subp. 2

The results of a performance test are not final until issuance of a review letter by

MPCA, unless specified otherwise by Minn. R. 7017.2001 - 7017.2060.

Minn. R. 7017.2020, subp. 4

CONTINUOUS EMISSION MONITOR REQUIREMENTS hdr

The owner or operator of an affected facility (EU003) shall install, calibrate,

maintain, and operate a continuous emission monitoring system for measuring and

recording sulfur dioxide emissions.

40 CFR Section 60.45(a)

Minn. R. 7011.0565

The owner or operator of an affected facility (EU003) shall install, calibrate,

maintain, and operate a continuous monitoring system for measuring and recording

nitrogen oxides emissions.

40 CFR Section 60.48b(b)

Minn. R. 7011.0565

The owner or operator of an affected facility (EU003) shall install, calibrate,

maintain and operate a continuous monitoring system for measuring and recording

opacity emissions.

40 CFR Section 60.48b(a)

Minn. R. 7011.0565

The Permittee shall use the data from the NOx CEM on SV001 to determine the

30-day rolling average NOx emission rate.

40 CFR Section 60.46b(e)(2)

Minn. R. 7011.0565

The owner or operator shall measure opacity, and all SO2, NOx, and CO2

emissions for each affect unit in accordance with 40 CFR Section 75.10.

40 CFR Section 75.10; Minn. R. 7017.1020
TABLE A: LIMITS AND OTHER REQUIREMENTS 12/23/09

Minnesota Power Inc - Hibbard Renewable Energy Ctr

13700015 - 004

Facility Name:

Permit Number:

A-15

Subject Item: EU 004 Boiler 4 

Associated Items: CE 003 Multiple Cyclone w/o Fly Ash Reinjection - Most Multiclones

CE 004 Electrostatic Precipitator - High Efficiency

GP 001 Boilers 3 and 4 

SV 001 Main Stack

What to do Why to do it

Total Particulate Matter: less than or equal to (0.025x + 0.027y)/(x+y) lb/mmBtu

based on a 24-hour average, where:

x = heat derived from the burning of coal over any hour in mmBtu

y = heat derived from the burning of wood and wood waste portion of sludge

and railroad ties over any hour in mmBtu

Title I Condition: Limit to restrict potential emission

increases to less than significant as defined by 40 CFR

Section 51.165 and 40 CFR Section 52.24. Also

ensures compliance with 40 CFR Section 60.43b.

Minn. R. 7007.4000 - 7007.4030

Opacity: less than or equal to 20 percent opacity using 6 Minute Average except for

one 6-minute period per hour of not greater than 27% opacity.

40 CFR Section 60.43b(f)

Minn. R. 7011.0565

Nitrogen Oxides: less than or equal to (0.6x + 0.4y +0.1z)/(x+y+z) lb/mmBtu based

on a 30 day rolling average, where:

x = heat derived from the burning of coal over any hour in mmBtu

y = heat derived from the burning of wood and wood waste portion of sludge

and railroad ties over any hour in mmBtu

z = heat input from natural gas in mmBtu

Once each hour, the Permittee shall use the NOx emission limit equation to

calculate the effective NOx emission limit.

Title I Condition: 40 CFR Section 52.21 BACT Limit; 40

CFR pt. 50. Also ensures compliance with 40 CFR

Section 60.44b.

Minn. R. 7007.3000

Carbon Monoxide: less than or equal to (0.35x + 0.45y + 0.04z)/(x+y+z) lb/mmBtu

based on a one-hour average, where:

x = heat derived from the burning of coal over any hour in mmBtu

y = heat derived from the burning of wood and wood waste portion of sludge

and railroad ties over any hour in mmBtu

z = heat input from natural gas in mmbtu

Title I Condition: 40 CFR Section 52.21 BACT Limit; 40

CFR pt. 50

Minn. R. 7007.3000

Sulfur Dioxide: less than or equal to (2.03Sx + 0.17y)/(x+y) lb/mmBtu based on a

one hour averaging period, where:

S = the allowed sulfur content in coal in percent by weight determined by fuel

sampling and analysis (see the following requirement for more detail).

x = heat derived from the burning of coal over any hour in mmBtu

y = heat derived from the burning of wood and wood waste portion of sludge

and railroad ties over any hour in mmBtu

Once each hour, the Permittee shall use the SO2 emission limit equation to

calculate the effective SO2 emission limit.

Title I Condition: 40 CFR Section 52.21 BACT Limit; 40

CFR pt. 50. Also ensures compliance with 40 CFR

Section 60.43(a)

Minn. R. 7007.3000

Limit of coal sulfur content (by weight):

 - 0.58% when burned alone or with natural gas or sludge,

 - may not exceed 0.9% at any time

 - When coal is being burned in combination with wood, the sulfur content limit

shall vary as follows:

 S = 8.13 X rE

 S = allowable percent sulfur by weight

 r = coal feed rate in tons per hour.

 E = the exponent (-0.88) of "r"

For use of this equation, r must be greater than or equal to 12. When r is less than

12, S = 0.9%.

Title I Conditions: PSD permit application and impacts

analysis

Minn. R. 7007.3000

The Permittee shall only burn wood (including creosoted railroad ties), coal, natural

gas, sludge from NewPage Duluth Paper Mill clarifier, oily cellulose-based sorbents

(including oily rags), oily coal and oily wood (coal or wood with oil spilled on it),

boiler cleaning agents, activated charcoal, hardboard rejects, and cellulose fill from

mattress recycling in EU004. Other materials may be combusted in this emission

unit for a short period of time during a trial burn as approved by an amendment to

this permit.

Title I Conditions: PSD permit application and impacts

analysis

Minn. R. 7007.3000
TABLE A: LIMITS AND OTHER REQUIREMENTS 12/23/09

Minnesota Power Inc - Hibbard Renewable Energy Ctr

13700015 - 004

Facility Name:

Permit Number:

A-16

Boiler cleaning agents burn requirements: agents must be EDTA type or

Ammonium Bromate, agents generated on-site, maximum of 5% of total fuel mass

input, oxygen must be 3% or greater, and agents may be burned only while the

boiler is operating at 75 percent of rated capacity or greater.

During the initial burn (after issuance of this permit) in EU 004 of boiler cleaning

agents, the Permittee shall monitor CO and opacity emissions to deterimine the

compliance status of CO and opacity emissions during the burn. Monitoring results

for the initial burn shall be submitted to the Agency. If compliance with the EU 004

CO and opacity limitations is shown, CO monitoring is not required during

subsequent boiler cleaning agent combustion events.

Minn. R. 7007.0800, subp. 2

Fuel usage rate limits:

 - 22 tons per hour for coal;

 - 67 tons per hour for wood;

 - 0.305 MMCF per hour for natural gas.

Title I Conditions: PSD permit application and impacts

analysis

Minn. R. 7007.3000

Fuel Sampling: The Permittee shall sample solid fuel as follows: 1) Daily composite

sampling for wood fuel; and 2) sample one coal delivery each week according to

the Permittee's sampling plans approved by the MPCA on November 18, 1987

(except the need for a duplicate gross 240 pound sample is not required).

Title I Conditions: PSD permit application and impacts

analysis

Minn. R. 7007.3000

Fuel Analysis: The Permittee shall analyze solid fuel samples using ASTM methods

or equivalent methods approved by the Commissioner. Samples shall be analyzed

for the following parameters:

Coal: Sulfur content in wt. %, heating value in Btus per lb.

Wood: Heating value in Btus per lb.

The average heating value for natural gas may be obtained from the vendor.

The Permittee shall maintain the records of all analyses for a period of 5 years from

the date of recording.

Minn. R. 7007.0800, subp. 2 and subp. 4

Maximum allowable heat input (based on 8-hour block averages):

 - 590 mmBtu/hour at any time

 - 380 mmBtu/hr from coal

 - 590 mmBtu/hr from wood

 - When wood fuel = 100% chipped railroad ties:

 maximum total heat input from all fuels = 326 mmBtu/hr,

 chipped railroad tie heat input shall not exceed 86% of total heat input, and

 coal heat input shall not be less than 14% of total heat input.

 - 305 mmBtu/hr from natural gas

Title I Conditions: PSD permit application and impacts

analysis

Minn. R. 7007.3000

Total heat input shall be determined using the following equations:

Total heat input to EU003 = x + y + z (not to exceed 590 mmBtu/hr)

 x = 380 - [(22-r) X (17.2)]

 y = 590 - [(67-s) X (8.8)]

 z = 305 - [(0.305-t) X (1000)]

x= heat derived from the burning of coal over any hour in mmBtu

y= heat derived from the burning of wood and wood waste portion of sludge and

railroad ties over any hour in mmBtu

z= heat derived from the burning of natural gas over any hour in mmBtu

r = coal feed rate to boiler in tons per hour

s = wood feed rate to boiler in tons per hour

t = natural gas feed rate to boiler in million cubic feet per hour

Title I Conditions: PSD permit application and impacts

analysis

Minn. R. 7007.3000

Monitoring and Recordkeeping for fuel usage and heat input:

The Permittee shall record the usage rate of each solid fuel on a daily basis, and

calculate and record the hourly average fuel use for each solid fuel by dividing the

daily fuel use by the number of hours of operation for that day. The Permittee shall

measure the natural gas usage rate, in million cubic feet per hour, using a fuel

meter.

The Permittee shall calculate and record the heat input during any hour from each

fuel, as well as the total heat input for that hour.

Heat content value of solid fuel shall be obtained from fuel sampling as required in

this permit. Heat content value of natural gas shall be obtained from the natural gas

vendor.

The Permittee shall maintain all fuel usage and heat input records for five years

from the date of recording.

Title I Conditions: PSD permit application and impacts

analysis

Minn. R. 7007.3000
TABLE A: LIMITS AND OTHER REQUIREMENTS 12/23/09

Minnesota Power Inc - Hibbard Renewable Energy Ctr

13700015 - 004

Facility Name:

Permit Number:

A-17

Record type and usage rate of each fuel on a daily basis, and calculate the hourly

average fuel use for each fuel type by dividing the daily fuel use by the number of

hours of operation for that day. Records shall be maintained for a minimum of 5

years.

Title I Conditions: PSD permit application and impacts

analysis

Minn. R. 7007.3000

Performance Test: due before end of each 60 months starting 04/01/2002 to

determine compliance with the Title I particulate matter emission limit while burning

coal, wood chips (including railroad ties), sludge, or any combination thereof. Tests

shall be conducted at intervals not to exceed 60 months between tests. Particulate

emissions testing shall be conducted in accordance with the procedures in 40 CFR

Section 60.46b(d) and Minn. R. 7017.2001 - 7017.2060 so that test results can also

be used to determine compliance with 40 CFR Section 60.43b.

Minn. R. 7017.2020, subp. 1

Performance Test: due before end of each 60 months following Initial Performance

Test to determine compliance with Title I CO emission limit while burning coal,

wood chips (including railroad ties), sludge, or any combination thereof. Tests shall

be conducted at intervals not to exceed 60 months between tests.

Minn. R. 7017.2020, subp. 1

Performance Test Notifications and Submittals:

Performance Tests are due as outlined in Tables A and B of the permit. See Table

B for additional testing requirements.

Performance Test Notification (written): due 30 days before each Performance Test

Performance Test Plan: due 30 days before each Performance Test

Performance Test Pre-test Meeting: due 7 days before each Performance Test

Performance Test Report: due 45 days after each Performance Test

Performance Test Report - CD or Microfiche Copy: due 105 days after each

Performance Test

The Notification, Test Plan, and Test Report may be submitted in alternative format

as allowed by Minn. R. 7017.2018.

Minn. Rs. 7017.2030, subp. 1-4, 7017.2018 and Minn.

R. 7017.2035, subp. 1-2

Boiler Alternative Operating Conditions for Performance Testing:

Alternative Operating Conditions during testing are defined as 90% to 100% of the

boiler's maximum normal (continuous) operating load or the maximum permitted

operating rate, whichever is lower. The basis for this number must be included in

the test plan. If testing is conducted at the alternative operating condition

established, an operating limit will not be established as a result of performance

testing.

In no case will the new operating rate limit be higher than allowed by an existing

permit condition.

Minn. R. 7017.2025, subp. 2(A) and 3(B)

Boiler Operating Conditions Not Meeting the Alternative Operating Conditions

During Performance Testing:

If performance testing is not conducted at or above the established alternative

operating condition, then the boiler operating rate will be limited on an 8-hour block

average based on the following:

(1) If the results of the performance test are greater than 80% of any applicable

emission limit for which compliance is demonstrated, then boiler operation will be

limited to the tested operating rate.

(2) If results are less than or equal to 80% of all applicable emission limits for which

compliance is demonstrated, boiler operation will be limited to 110% of the tested

operating rate.

In no case will the new operating rate limit be higher than allowed by an existing

permit condition.

Minn. R. 7017.2025, subp. 3(B)

STET (Short Term Emergency and Testing) Operating hours limit:

The boiler may operate up to 40 hours per year to demonstrate the Uniform Rating

of Generating Equipment (URGE) capacity and to meet emergency energy supply

needs. Maintain documentation of all STET operation to demonstrate compliance

with this limit. The boiler must meet emission limits during STET operation.

Minn. R. 7007.0800, subp. 2
TABLE A: LIMITS AND OTHER REQUIREMENTS 12/23/09

Minnesota Power Inc - Hibbard Renewable Energy Ctr

13700015 - 004

Facility Name:

Permit Number:

A-18

STET Operation Definition that applies to Boilers that Meet or do Not Meet the

Alternative Operating Condition for Performance Testing:

If performance test results demonstrate compliance at 80% or less of any

applicable emission limits for any tested pollutant, STET operation is defined as

operation beyond 110% of the average operating rate achieved during that

performance test.

If performance test results demonstrate compliance at greater than 80% any

applicable emision limit for any tested pollutant, STET operation is defined as

operation beyond 100% of the average operating rate achieved during that

performance test.

In no case will STET operation be higher than allowed by an existing permit

condition.

Minn. R. 7007.0800, subp. 2

The results of a performance test are not final until issuance of a review letter by

MPCA, unless specified otherwise by Minn. R. 7017.2001 - 7017.2060.

Minn. R. 7017.2020, subp. 4

CONTINUOUS EMISSION MONITOR REQUIREMENTS hdr

The owner or operator of an affected facility (EU004) shall install, calibrate,

maintain, and operate a continuous emission monitoring system for measuring and

recording sulfur dioxide emissions.

40 CFR Section 60.45(a)

The owner or operator of an affected facility (EU004) shall install, calibrate,

maintain, and operate a continuous monitoring system for measuring and recording

nitrogen oxides emissions.

40 CFR Section 60.48b(b)

Minn. R. 7011.0565

The owner or operator of an affected facility (EU004) shall install, calibrate,

maintain and operate a continuous monitoring system for measuring and recording

opacity emissions.

40 CFR Section 60.48b(a)

Minn. R. 7011.0565

The Permittee shall use the data from the NOx CEM on SV001 to determine the

30-day rolling average NOx emission rate.

40 CFR Section 60.46b(e)(2)

Minn. R. 7011.0565

The owner or operator shall measure opacity, and all SO2, NOx, and CO2

emissions for each affect unit in accordance with 40 CFR Section 75.10

40 CFR Section 75.10; Minn. R. 7017.1020
TABLE A: LIMITS AND OTHER REQUIREMENTS 12/23/09

Minnesota Power Inc - Hibbard Renewable Energy Ctr

13700015 - 004

Facility Name:

Permit Number:

A-19

Subject Item: CE 002 Electrostatic Precipitator - High Efficiency

Associated Items: EU 003 Boiler 3 

What to do Why to do it

Total Particulate Matter: greater than or equal to 99 percent control efficiency Minn. R. 7007.0800, subp. 2 and 14

The Permittee shall operate and maintain CE002 at all times that any emission unit

controlled by CE002 is in operation. The Permittee shall document periods of

non-operation of the control equipment.

Minn. R. 7007.0800, subp. 2 and 14

Corrective Actions: The Permittee shall take corrective action as soon as possible if

any of the following occur:

- excessive visible emissions are observed;

- any recorded operating parameter is outside the required operating range; or

- CE002 or any of its components are found during the inspections to need repair.

Corrective actions shall return operation to within the permitted range, eliminate

excessive visible emissions, and/or include completion of necessary repairs

identified during the inspection, as applicable. Corrective actions include, but are

not limited to, those outlined in the O & M Plan for CE002. The Permittee shall keep

a record of the type and date of any corrective action taken for each filter.

Minn. R. 7007.0800, subp. 4, 5, and 14

Periodic Inspections: At least once per calendar year, or as required by the

manufacturing specifications, the Permittee shall inspect the control equipment

components. The Permittee shall maintain a written record of these inspections.

Minn. R. 7007.0800, subp. 4, 5 and 14

COMPLIANCE ASSURANCE MONITORING hdr

The owner or operator shall comply with the approved monitoring for Total

Secondary Power. The owner or operator shall measure the indicators with a

Distributed Control System.

Parameter range indicating normal operation is:

Total Secondary power greater than or equal to 25 kw as a 3-hour average

Secondary Power for a field is calculated from measurement of seconday voltage

and current. Total Seconday Power is the sum of the power for all fields. Voltage

and current are measured digitally on a continuous basis and used to calculate

power every 15 minutes. Hourly average power is calculated using 4 consecutive

15-minute calculated values. An excursion from the specfied minimum of 25 kw is

based on a three-hour rolling average.

40 CFR Section 64.3(b) or (d)

Minn. R. 7017.0200

The owner or operator shall conduct the monitoring required under 40 CFR pt. 64

upon permit issuance.

40 CFR Section 64.7(a)

Minn. R. 7017.0200

The owner or operator shall maintain the monitoring instruments and recorders,

including but not limited to maintainig necessary parts for routine repairs of the

monitoring equipment.

40 CFR Section 64.7(b)

Minn. R. 7017.0200

Continuous Operation: Except for, as applicable, monitoring malfunctions,

associated repairs, and required quality assurance or control activities, the owner

or operator shall conduct all monitoring in continuous operation at all times the

pollutant-specific emissions unit is operating.

40 CFR Section 64.7(c)

Minn. R. 7017.0200

Response to excursions or exceedances: Upon detecting an excursion or

exceedance, the owner or operator shall restore operation of the pollutant-specific

emissions unit and/or air pollution control equipment to its normal or usual manner

of operation as expeditiously as practicable in accordance with good air pollution

control practices for minimizing emissions.

40 CFR Section 64.7(d)(1)

Minn. R. 7017.0200

Documentation of need for improved monitoring: After approval of monitoring

under this part, if the owner or operator identifies a failure to achieve compliance

with an emission limitiation or standard for which the approved monitoring did not

provide an indication of an excursion or exceedance while providing valid data, or

the results of compliance or performance testing document a need to modify the

existing indicator ranges or designated conditions, the owner or operator shall

promptly notify the permitting authority and, if necessary, submit a proposed

modification to the part 70 permit to address the necessary monitoring changes.

40 CFR Section 64.7(e)

Minn. R. 7017.0200

The owner or operator shall maintain records of monitoring data monitor

performance data, corrective actions taken, any written quality improvement plan

required pursuant to 64.8 and any activities undertaken to implement a quality

improvement plan, and other supporting information required to be maintained.

The owner or operator may maintain records on alternative media, such as

microfilm, computer files, magnetic tape disks, or microfiche, provided that the use

of such alternative media allows for expeditious inspection and review, and does

not conflict with other applicable recordkeeping requirements.

40 CFR Section 64.9(b)

Minn. R. 7017.0200
TABLE A: LIMITS AND OTHER REQUIREMENTS 12/23/09

Minnesota Power Inc - Hibbard Renewable Energy Ctr

13700015 - 004

Facility Name:

Permit Number:

A-20

The owner or operator shall report exceedances or excursions under 64.7 and 64.8

when the exceedance or excursion are greater than the limit and averaging period.

The owner/operator shall submit this report with the Semiannual Deviations Report.

40 CFR Section 64.9(a)(2)(i)

Minn. R. 7017.0200
TABLE A: LIMITS AND OTHER REQUIREMENTS 12/23/09

Minnesota Power Inc - Hibbard Renewable Energy Ctr

13700015 - 004

Facility Name:

Permit Number:

A-21

Subject Item: CE 004 Electrostatic Precipitator - High Efficiency

Associated Items: EU 004 Boiler 4 

What to do Why to do it

Total Particulate Matter: greater than or equal to 99 percent control efficiency Minn. R. 7007.0800, subp. 2 and 14

The Permittee shall operate and maintain CE004 at all times that any emission unit

controlled by CE004 is in operation. The Permittee shall document periods of

non-operation of the control equipment.

Minn. R. 7007.0800, subp. 2 and 14

Corrective Actions: The Permittee shall take corrective action as soon as possible if

any of the following occur:

- excessive visible emissions are observed;

- any recorded operating parameter is outside the required operating range; or

- CE004 or any of its components are found during the inspections to need repair.

Corrective actions shall return operation to within the permitted range, eliminate

excessive visible emissions, and/or include completion of necessary repairs

identified during the inspection, as applicable. Corrective actions include, but are

not limited to, those outlined in the O & M Plan for CE004. The Permittee shall keep

a record of the type and date of any corrective action taken for each filter.

Minn. R. 7007.0800, subp. 4, 5, and 14

Periodic Inspections: At least once per calendar year, or as required by the

manufacturing specifications, the Permittee shall inspect the control equipment

components. The Permittee shall maintain a written record of these inspections.

Minn. R. 7007.0800, subp. 4, 5 and 14

COMPLIANCE ASSURANCE MONITORING hdr

The owner or operator shall comply with the approved monitoring for Total

Secondary Power. The owner or operator shall measure the indicators with a

Distributed Control System.

Parameter range indicating normal operation is:

Total Secondary power greater than or equal to 25 kw as a 3-hour average

Secondary Power for a field is calculated from measurement of seconday voltage

and current. Total Seconday Power is the sum of the power for all fields. Voltage

and current are measured digitally on a continuous basis and used to calculate

power every 15 minutes. Hourly average power is calculated using 4 consecutive

15-minute calculated values. An excursion from the specfied minimum of 25 kw is

based on a three-hour rolling average.

40 CFR Section 64.3(b) or (d)

Minn. R. 7017.0200

The owner or operator shall conduct the monitoring required under 40 CFR pt. 64

upon permit issuance.

40 CFR Section 64.7(a)

Minn. R. 7017.0200

The owner or operator shall maintain the monitoring instruments and recorders,

including but not limited to maintainig necessary parts for routine repairs of the

monitoring equipment.

40 CFR Section 64.7(b)

Minn. R. 7017.0200

Continuous Operation: Except for, as applicable, monitoring malfunctions,

associated repairs, and required quality assurance or control activities, the owner

or operator shall conduct all monitoring in continuous operation at all times the

pollutant-specific emissions unit is operating.

40 CFR Section 64.7(c)

Minn. R. 7017.0200

Response to excursions or exceedances: Upon detecting an excursion or

exceedance, the owner or operator shall restore operation of the pollutant-specific

emissions unit and/or air pollution control equipment to its normal or usual manner

of operation as expeditiously as practicable in accordance with good air pollution

control practices for minimizing emissions.

40 CFR Section 64.7(d)(1)

Minn. R. 7017.0200

Documentation of need for improved monitoring: After approval of monitoring

under this part, if the owner or operator identifies a failure to achieve compliance

with an emission limitiation or standard for which the approved monitoring did not

provide an indication of an excursion or exceedance while providing valid data, or

the results of compliance or performance testing document a need to modify the

existing indicator ranges or designated conditions, the owner or operator shall

promptly notify the permitting authority and, if necessary, submit a proposed

modification to the part 70 permit to address the necessary monitoring changes.

40 CFR Section 64.7(e)

Minn. R. 7017.0200

The owner or operator shall maintain records of monitoring data monitor

performance data, corrective actions taken, any written quality improvement plan

required pursuant to 64.8 and any activities undertaken to implement a quality

improvement plan, and other supporting information required to be maintained.

The owner or operator may maintain records on alternative media, such as

microfilm, computer files, magnetic tape disks, or microfiche, provided that the use

of such alternative media allows for expeditious inspection and review, and does

not conflict with other applicable recordkeeping requirements.

40 CFR Section 64.9(b)

Minn. R. 7017.0200
TABLE A: LIMITS AND OTHER REQUIREMENTS 12/23/09

Minnesota Power Inc - Hibbard Renewable Energy Ctr

13700015 - 004

Facility Name:

Permit Number:

A-22

The owner or operator shall report exceedances or excursions under 64.7 and 64.8

when the exceedance or excursion are greater than the limit and averaging period.

The owner/oprator shall submit this report with the Semiannual Deviations Report.

40 CFR Section 64.9(a)(2)(i)

Minn. R. 7017.0200
TABLE A: LIMITS AND OTHER REQUIREMENTS 12/23/09

Minnesota Power Inc - Hibbard Renewable Energy Ctr

13700015 - 004

Facility Name:

Permit Number:

A-23

Subject Item: MR 101 SO2 monitor - low range

Associated Items: GP 001 Boilers 3 and 4 

What to do Why to do it

CEMS QA/QC The owner or operator of an affected facility shall operate, calibrate,

and maintain each CEMS according to the QA/QC procedures in 40 CFR pt. 75,

Appendix B as amended.

40 CFR Section 75.21; Minn. R. 7017.1020

Daily Calibration Error (CE) Test: conduct daily CE testing on all CEMS required by

the Acid Rain Program, in accordance with 40 CFR pt. 75 App B.

40 CFR pt. 75 App B, section 2.1; Minn. R. 7017.1020

CEMS Relative Accuracy Test Audit (RATA): due before end of each calendar

half-year following CEM Certification Test, i.e., once every two successive QA

operating quarters (calendar quarter in which there are at least 168 unit operating

hours). Conduct a RATA on all CEMS required by the Acid Rain Program, in

accordance with 40 CFR pt. 75, Appendix B. Relative accuracy test audits may be

performed annually (i.e., once every four successive QA operating quarters, rather

than once every two successive QA operating quarters) if any of the conditions

listed in 40 CFR pt. 75, Appendix B, Section 2.3.1.2(a) through Section 2.3.1.2(i)

are met.

40 CFR pt. 75, Appendix B, section 2.3.1; Minn. R.

7017.1020

Linearity (Acid Rain Program): due before end of each QA operating quarter (as

defined in Section 72.) in accordance with procedures in 40 CFR pt. 75, Appendix

B, Sections 2.2.1 and 2.2.2, and Appendix A, Section 6.2.

Perform a leak check at least once during each QA operating quarter (calendar

quarter in which there are at least 168 unit operating hours) and no less than 30

days apart.

40 CFR pt. 75, Appendix B, section 2.2.1 & section

2.2.2; Minn. R. 7017.1020

Recordkeeping: maintain records of the occurrence and duration of any startup,

shutdown, or malfunction in the operation of the facility including any malfunction of

the air pollution control equipment or any periods during which a continuous

monitoring system or monitoring device is inoperative.

40 CFR Section 60.7(b)

Recordkeeping: Keep on site at the source each of the following documents for a

period of 5 years from the date the document is created: The certificate of

representation, all emissions monitoring information, copies of all reports,

compliance certifications, and other submissions or records made under the Acid

Rain Program, copies of all documents used to complete an acid rain permit

application.

40 CFR Section 72.9(f)(l)

Linearity Test Results Summary: due 30 days after end of each calendar quarter

following Linearity and Leak Check Test if performed.

Minn. R. 7017.1180, subp. 4

Relative Accuracy Test Audit (RATA) Notification: due 30 days before CEMS

Relative Accuracy Test Audit (RATA)).

Minn. R. 7017.1180, subp. 2

Relative Accuracy Test Audit (RATA) Results Summary: due 30 days after end of

each calender quarter in which the CEMS RATA was conducted.

Minn. R. 7017.1180, subp. 3

Recordkeeping: The owner or operator must retain records of all CEMS monitoring

data and support information for a period of five years from the date of the

monitoring sample, measurement or report. Records shall be kept at the source.

Minn. R. 7017.1130; and 40 CFR Section 75.50

Continuous Operation: CEMS must be operated and data recorded during all

periods of emission unit operation including periods of emission unit start-up,

shutdown, or malfunction except for periods of acceptable monitor downtime. This

requirement applies whether or not a numerical emission limit applies during these

periods. A CEMS must not be bypassed except in emergencies where failure to

bypass would endanger human health, safety, or plant equipment.

Acceptable monitor downtime includes reasonable periods as listed in Items A, B,

C and D of Minn. R. 7017.1090, subp. 2.

40 CFR section 60.13(e), subp. 6; Minn. R. 7017.1090,

subp. 1
TABLE A: LIMITS AND OTHER REQUIREMENTS 12/23/09

Minnesota Power Inc - Hibbard Renewable Energy Ctr

13700015 - 004

Facility Name:

Permit Number:

A-24

Subject Item: MR 102 NOx monitor

Associated Items: GP 001 Boilers 3 and 4 

What to do Why to do it

CEMS QA/QC The owner or operator of an affected facility shall operate, calibrate,

and maintain each CEMS according to the QA/QC procedures in 40 CFR pt. 75,

Appendix B as amended.

40 CFR Section 75.21; Minn. R. 7017.1020

Daily Calibration Error (CE) Test: conduct daily CE testing on all CEMS required by

the Acid Rain Program, in accordance with 40 CFR pt. 75 App B.

40 CFR pt. 75 App B, section 2.1; Minn. R. 7017.1020

CEMS Relative Accuracy Test Audit (RATA): due before end of each calendar

half-year following CEM Certification Test, i.e., once every two successive QA

operating quarters (calendar quarter in which there are at least 168 unit operating

hours). Conduct a RATA on all CEMS required by the Acid Rain Program, in

accordance with 40 CFR pt. 75, Appendix B. Relative accuracy test audits may be

performed annually (i.e., once every four successive QA operating quarters, rather

than once every two successive QA operating quarters) if any of the conditions

listed in 40 CFR pt. 75, Appendix B, Section 2.3.1.2(a) through Section 2.3.1.2(i)

are met.

40 CFR pt. 75, Appendix B, section 2.3.1; Minn. R.

7017.1020

Linearity (Acid Rain Program): due before end of each QA operating quarter (as

defined in Section 72.) in accordance with procedures in 40 CFR pt. 75, Appendix

B, Sections 2.2.1 and 2.2.2, and Appendix A, Section 6.2.

Perform a leak check at least once during each QA operating quarter (calendar

quarter in which there are at least 168 unit operating hours) and no less than 30

days apart.

40 CFR pt. 75, Appendix B, section 2.2.1 & section

2.2.2; Minn. R. 7017.1020

Recordkeeping: maintain records of the occurrence and duration of any startup,

shutdown, or malfunction in the operation of the facility including any malfunction of

the air pollution control equipment or any periods during which a continuous

monitoring system or monitoring device is inoperative.

40 CFR Section 60.7(b)

Recordkeeping: Keep on site at the source each of the following documents for a

period of 5 years from the date the document is created: The certificate of

representation, all emissions monitoring information, copies of all reports,

compliance certifications, and other submissions or records made under the Acid

Rain Program, copies of all documents used to complete an acid rain permit

application.

40 CFR Section 72.9(f)(l)

Linearity Test Results Summary: due 30 days after end of each calendar quarter

following Linearity and Leak Check Test if performed.

Minn. R. 7017.1180, subp. 4

Relative Accuracy Test Audit (RATA) Notification: due 30 days before CEMS

Relative Accuracy Test Audit (RATA)).

Minn. R. 7017.1180, subp. 2

Relative Accuracy Test Audit (RATA) Results Summary: due 30 days after end of

each calender quarter in which the CEMS RATA was conducted.

Minn. R. 7017.1180, subp. 3

Recordkeeping: The owner or operator must retain records of all CEMS monitoring

data and support information for a period of five years from the date of the

monitoring sample, measurement or report. Records shall be kept at the source.

Minn. R. 7017.1130; and 40 CFR Section 75.50

Continuous Operation: CEMS must be operated and data recorded during all

periods of emission unit operation including periods of emission unit start-up,

shutdown, or malfunction except for periods of acceptable monitor downtime. This

requirement applies whether or not a numerical emission limit applies during these

periods. A CEMS must not be bypassed except in emergencies where failure to

bypass would endanger human health, safety, or plant equipment.

Acceptable monitor downtime includes reasonable periods as listed in Items A, B,

C and D of Minn. R. 7017.1090, subp. 2.

40 CFR section 60.13(e), subp. 6; Minn. R. 7017.1090,

subp. 1
TABLE A: LIMITS AND OTHER REQUIREMENTS 12/23/09

Minnesota Power Inc - Hibbard Renewable Energy Ctr

13700015 - 004

Facility Name:

Permit Number:

A-25

Subject Item: MR 103 CO2 monitor

Associated Items: GP 001 Boilers 3 and 4 

What to do Why to do it

CEMS QA/QC The owner or operator of an affected facility shall operate, calibrate,

and maintain each CEMS according to the QA/QC procedures in 40 CFR pt. 75,

Appendix B as amended.

40 CFR Section 75.21; Minn. R. 7017.1020

Daily Calibration Error (CE) Test: conduct daily CE testing on all CEMS required by

the Acid Rain Program, in accordance with 40 CFR pt. 75 App B.

40 CFR pt. 75 App B, section 2.1; Minn. R. 7017.1020

CEMS Relative Accuracy Test Audit (RATA): due before end of each calendar

half-year following CEM Certification Test, i.e., once every two successive QA

operating quarters (calendar quarter in which there are at least 168 unit operating

hours). Conduct a RATA on all CEMS required by the Acid Rain Program, in

accordance with 40 CFR pt. 75, Appendix B. Relative accuracy test audits may be

performed annually (i.e., once every four successive QA operating quarters, rather

than once every two successive QA operating quarters) if any of the conditions

listed in 40 CFR pt. 75, Appendix B, Section 2.3.1.2(a) through Section 2.3.1.2(i)

are met.

40 CFR pt. 75, Appendix B, section 2.3.1; Minn. R.

7017.1020

Linearity (Acid Rain Program): due before end of each QA operating quarter (as

defined in Section 72.) in accordance with procedures in 40 CFR pt. 75, Appendix

B, Sections 2.2.1 and 2.2.2, and Appendix A, Section 6.2.

Perform a leak check at least once during each QA operating quarter (calendar

quarter in which there are at least 168 unit operating hours) and no less than 30

days apart.

40 CFR pt. 75, Appendix B, section 2.2.1 & section

2.2.2; Minn. R. 7017.1020

Recordkeeping: maintain records of the occurrence and duration of any startup,

shutdown, or malfunction in the operation of the facility including any malfunction of

the air pollution control equipment or any periods during which a continuous

monitoring system or monitoring device is inoperative.

40 CFR Section 60.7(b)

Recordkeeping: Keep on site at the source each of the following documents for a

period of 5 years from the date the document is created: The certificate of

representation, all emissions monitoring information, copies of all reports,

compliance certifications, and other submissions or records made under the Acid

Rain Program, copies of all documents used to complete an acid rain permit

application.

40 CFR Section 72.9(f)(l)

Linearity Test Results Summary: due 30 days after end of each calendar quarter

following Linearity and Leak Check Test if performed.

Minn. R. 7017.1180, subp. 4

Relative Accuracy Test Audit (RATA) Notification: due 30 days before CEMS

Relative Accuracy Test Audit (RATA)).

Minn. R. 7017.1180, subp. 2

Relative Accuracy Test Audit (RATA) Results Summary: due 30 days after end of

each calender quarter in which the CEMS RATA was conducted.

Minn. R. 7017.1180, subp. 3

Recordkeeping: The owner or operator must retain records of all CEMS monitoring

data and support information for a period of five years from the date of the

monitoring sample, measurement or report. Records shall be kept at the source.

Minn. R. 7017.1130; and 40 CFR Section 75.50

Continuous Operation: CEMS must be operated and data recorded during all

periods of emission unit operation including periods of emission unit start-up,

shutdown, or malfunction except for periods of acceptable monitor downtime. This

requirement applies whether or not a numerical emission limit applies during these

periods. A CEMS must not be bypassed except in emergencies where failure to

bypass would endanger human health, safety, or plant equipment.

Acceptable monitor downtime includes reasonable periods as listed in Items A, B,

C and D of Minn. R. 7017.1090, subp. 2.

40 CFR section 60.13(e), subp. 6; Minn. R. 7017.1090,

subp. 1
TABLE A: LIMITS AND OTHER REQUIREMENTS 12/23/09

Minnesota Power Inc - Hibbard Renewable Energy Ctr

13700015 - 004

Facility Name:

Permit Number:

A-26

Subject Item: MR 104 SO2 monitor - high range

Associated Items: GP 001 Boilers 3 and 4 

What to do Why to do it

CEMS QA/QC The owner or operator of an affected facility shall operate, calibrate,

and maintain each CEMS according to the QA/QC procedures in 40 CFR pt. 75,

Appendix B as amended.

40 CFR Section 75.21; Minn. R. 7017.1020

Daily Calibration Error (CE) Test: conduct daily CE testing on all CEMS required by

the Acid Rain Program, in accordance with 40 CFR pt. 75 App B.

40 CFR pt. 75 App B, section 2.1; Minn. R. 7017.1020

CEMS Relative Accuracy Test Audit (RATA): due before end of each calendar

half-year following CEM Certification Test, i.e., once every two successive QA

operating quarters (calendar quarter in which there are at least 168 unit operating

hours). Conduct a RATA on all CEMS required by the Acid Rain Program, in

accordance with 40 CFR pt. 75, Appendix B. Relative accuracy test audits may be

performed annually (i.e., once every four successive QA operating quarters, rather

than once every two successive QA operating quarters) if any of the conditions

listed in 40 CFR pt. 75, Appendix B, Section 2.3.1.2(a) through Section 2.3.1.2(i)

are met.

40 CFR pt. 75, Appendix B, section 2.3.1; Minn. R.

7017.1020

Linearity (Acid Rain Program): due before end of each QA operating quarter (as

defined in Section 72.) in accordance with procedures in 40 CFR pt. 75, Appendix

B, Sections 2.2.1 and 2.2.2, and Appendix A, Section 6.2.

Perform a leak check at least once during each QA operating quarter (calendar

quarter in which there are at least 168 unit operating hours) and no less than 30

days apart.

40 CFR pt. 75, Appendix B, section 2.2.1 & section

2.2.2; Minn. R. 7017.1020

Recordkeeping: maintain records of the occurrence and duration of any startup,

shutdown, or malfunction in the operation of the facility including any malfunction of

the air pollution control equipment or any periods during which a continuous

monitoring system or monitoring device is inoperative.

40 CFR Section 60.7(b)

Recordkeeping: Keep on site at the source each of the following documents for a

period of 5 years from the date the document is created: The certificate of

representation, all emissions monitoring information, copies of all reports,

compliance certifications, and other submissions or records made under the Acid

Rain Program, copies of all documents used to complete an acid rain permit

application.

40 CFR Section 72.9(f)(l)

Linearity Test Results Summary: due 30 days after end of each calendar quarter

following Linearity and Leak Check Test if performed.

Minn. R. 7017.1180, subp. 4

Relative Accuracy Test Audit (RATA) Notification: due 30 days before CEMS

Relative Accuracy Test Audit (RATA)).

Minn. R. 7017.1180, subp. 2

Relative Accuracy Test Audit (RATA) Results Summary: due 30 days after end of

each calender quarter in which the CEMS RATA was conducted.

Minn. R. 7017.1180, subp. 3

Recordkeeping: The owner or operator must retain records of all CEMS monitoring

data and support information for a period of five years from the date of the

monitoring sample, measurement or report. Records shall be kept at the source.

Minn. R. 7017.1130; and 40 CFR Section 75.50

Continuous Operation: CEMS must be operated and data recorded during all

periods of emission unit operation including periods of emission unit start-up,

shutdown, or malfunction except for periods of acceptable monitor downtime. This

requirement applies whether or not a numerical emission limit applies during these

periods. A CEMS must not be bypassed except in emergencies where failure to

bypass would endanger human health, safety, or plant equipment.

Acceptable monitor downtime includes reasonable periods as listed in Items A, B,

C and D of Minn. R. 7017.1090, subp. 2.

40 CFR section 60.13(e), subp. 6; Minn. R. 7017.1090,

subp. 1
TABLE A: LIMITS AND OTHER REQUIREMENTS 12/23/09

Minnesota Power Inc - Hibbard Renewable Energy Ctr

13700015 - 004

Facility Name:

Permit Number:

A-27

Subject Item: MR 107 flow monitor

Associated Items: GP 001 Boilers 3 and 4 

What to do Why to do it

QA/QC The owner or operator of an affected facility shall operate, calibrate, and

maintain each continuous monitor according to the QA/QC procedures in 40 CFR

pt. 75, Appendix B as amended.

40 CFR Section 75.21; Minn. R. 7017.1020

Daily Calibration Error (CE) Test: conduct daily CE testing on all continuous

monitors required by the Acid Rain Program, in accordance with 40 CFR pt. 75 App

B.

40 CFR pt. 75 App B, section 2.1; Minn. R. 7017.1020

Relative Accuracy Test Audit (RATA): due before end of each calendar half-year

following Certification Test, i.e., once every two successive QA operating quarters

(calendar quarter in which there are at least 168 unit operating hours). Conduct a

RATA required by the Acid Rain Program, in accordance with 40 CFR pt. 75,

Appendix B. Relative accuracy test audits may be performed annually (i.e., once

every four successive QA operating quarters, rather than once every two

successive QA operating quarters) if any of the conditions listed in 40 CFR pt. 75,

Appendix B, Section 2.3.1.2(a) through Section 2.3.1.2(i) are met.

40 CFR pt. 75, Appendix B, section 2.3.1; Minn. R.

7017.1020

Linearity and Leak Check Test (Acid Rain Program): due before end of each QA

operating quarter (as defined in Section 72.) in accordance with procedures in 40

CFR pt. 75, Appendix B, Sections 2.2.1 and 2.2.2, and Appendix A, Section 6.2.

Perform a leak check at least once during each QA operating quarter (calendar

quarter in which there are at least 168 unit operating hours) and no less than 30

days apart.

40 CFR pt. 75, Appendix B, section 2.2.1 & section

2.2.2; Minn. R. 7017.1020

Recordkeeping: maintain records of the occurrence and duration of any startup,

shutdown, or malfunction in the operation of the facility including any malfunction of

the air pollution control equipment or any periods during which a continuous

monitoring system or monitoring device is inoperative.

40 CFR Section 60.7(b)

Recordkeeping: Keep on site at the source each of the following documents for a

period of 5 years from the date the document is created: The certificate of

representation, all emissions monitoring information, copies of all reports,

compliance certifications, and other submissions or records made under the Acid

Rain Program, copies of all documents used to complete an acid rain permit

application.

40 CFR Section 72.9(f)(l)

Linearity Test Results Summary: due 30 days after end of each calendar quarter

following Linearity and Leak Check Test if performed.

Minn. R. 7017.1180, subp. 4

Relative Accuracy Test Audit (RATA) Notification: due 30 days before continuous

monitor Relative Accuracy Test Audit (RATA)).

Minn. R. 7017.1180, subp. 2

Relative Accuracy Test Audit (RATA) Results Summary: due 30 days after end of

each calender quarter in which the RATA was conducted.

Minn. R. 7017.1180, subp. 3

Recordkeeping: The owner or operator must retain records of all monitoring data

and support information for a period of five years from the date of the monitoring

sample, measurement or report. Records shall be kept at the source.

Minn. R. 7017.1130; and 40 CFR Section 75.50

Continuous Operation: Continuous monitors must be operated and data recorded

during all periods of emission unit operation including periods of emission unit

start-up, shutdown, or malfunction except for periods of acceptable monitor

downtime. This requirement applies whether or not a numerical emission limit

applies during these periods. A monitor must not be bypassed except in

emergencies where failure to bypass would endanger human health, safety, or

plant equipment.

Acceptable monitor downtime includes reasonable periods as listed in Items A, B,

C and D of Minn. R. 7017.1090, subp. 2.

40 CFR section 60.13(e), subp. 6; Minn. R. 7017.1090,

subp. 1
TABLE A: LIMITS AND OTHER REQUIREMENTS 12/23/09

Minnesota Power Inc - Hibbard Renewable Energy Ctr

13700015 - 004

Facility Name:

Permit Number:

A-28

Subject Item: MR 108 opacity monitor

Associated Items: GP 001 Boilers 3 and 4 

What to do Why to do it

All COMS shall complete a minimum of one cycle of sampling and analyzing for

each successive 10-second period and one cycle of data for each successive

6-minute period.

Minn. R. 7017.1200, subp. 1, 2 & 3; 40 CFR Section

60.13(e)(1); 40 CFR Section 60.13(h)

Continuous Operation: COMS must be operated and data recorded during all

periods of emission unit operation including periods of emission unit start-up,

shutdown, or malfunction except for periods of acceptable monitor downtime. This

requirement applies whether or not a numerical emission limit applies during these

periods. A COMS must not be bypassed except in emergencies where failure to

bypass would endanger human health, safety, or plant equipment.

Acceptable monitor downtime includes reasonable periods as listed in Items A, B,

C and D of Minn. R. 7017.1090, subp. 2.

Minn. R. 7017.1090, subp. 1; 40 CFR Section 60.13(e)

COMS Daily Calibration Drift Check: The Permittee must automatically, intrinsic to

the opacity monitor, check the zero and upscale (span) calibration drifts at least

once daily. The acceptable range is as defined in 40 CFR pt. 60, Appendix B, PS-1.

For COMS without automatic zero adjustments, the optical surfaces exposed to the

effluent gases shall be cleaned prior to performing the zero and span drift

adjustments. For COMS with automatic zero adjustments, the optical surfaces shall

be cleaned when the cumulative automatic zero compensation exceeds 4 percent

opacity.

Minimum procedures must include an automated method for producing a simulated

zero opacity condition and an upscale opacity condition as specified in 40 CFR

60.13(d)(2).

Minn. R. 7017.1210, subp. 2; 40 CFR Section

60.13(d)(l) regarding COMS and 60.13(d)(2)

COMS Calibration Error Audit: due before end of each calendar half-year following

COMS Certification Test or Permit Issuance. Conduct three point calibration error

audits at least 3 months apart but no greater than 8 months apart. Conduct audits

in accordance with Minn. R. 7017.1210, subp. 3.

Minn. R. 7017.1210, subp. 3

COMS Calibration Error Audit Results Summary: due 30 days after end of each

calendar quarter in which the COMS calibration error audit was completed.

Minn. R. 7017.1220

Notification that Continuous Opacity Monitoring System (COMS) data will be used

to determine compliance with opacity standard during performance test: due 30

days prior to the date of performance test.

40 CFR Section 60.7(a)(7)

Permittee is allowed to measure the combined effluent from two or more affected

facilities subject to the same emission standard.

40 CFR Section 60.13(g)
TABLE B: SUBMITTALS

Facility Name: Minnesota Power Inc - Hibbard Renewable Energy Ctr

Permit Number: 13700015 - 004

B-1 12/23/09

Table B lists most of the submittals required by this permit. Please note that some submittal requirements may appear in Table A

or, if applicable, within a compliance schedule located in Table C. Table B is divided into two sections in order to separately list

one-time only and recurrent submittal requirements.

Send submittals that are required to be submitted to the U.S. EPA regional office to:

 Mr. George Czerniak

 Air and Radiation Branch

 EPA Region V

 77 West Jackson Boulevard

 Chicago, Illinois 60604

Each submittal must be postmarked or received by the date specified in the applicable Table. Those submittals required by parts

7007.0100 to 7007.1850 must be certified by a responsible official, defined in Minn. R. 7007.0100, subp. 21. Other submittals shall

be certified as appropriate if certification is required by an applicable rule or permit condition.

Send submittals that are required by the Acid Rain Program to:

 U.S. Environmental Protection Agency

 Clean Air Markets Division

 1200 Pennsylvania Avenue NW (6204N)

 Washington, D.C. 20460

Send any application for a permit or permit amendment to:

 AQ Permit Technical Advisor

 Industrial Division

 Minnesota Pollution Control Agency

 520 Lafayette Road North

 St. Paul, Minnesota 55155-4194

Also, where required by an applicable rule or permit condition, send to the Permit Technical Advisor notices of:

- accumulated insignificant activities,

- installation of control equipment,

- replacement of an emissions unit, and

- changes that contravene a permit term.

Unless another person is identified in the applicable Table, send all other submittals to:

 AQ Compliance Tracking Coordinator

 Industrial Division

 Minnesota Pollution Control Agency

 520 Lafayette Road North

 St. Paul, Minnesota 55155-4194
TABLE B: ONE TIME SUBMITTALS OR NOTIFICATIONS

Facility Name: Minnesota Power Inc - Hibbard Renewable Energy Ctr

Permit Number: 13700015 - 004

B-2 12/23/09

What to send When to send Portion of Facility Affected

Application for Permit Reissuance due 180 days before expiration of Existing

Permit

Total Facility

Relative Accuracy Test Audit (RATA)

Notification

 due 30 days before CEMS Relative Accuracy

Test Audit (RATA) .

MR101, MR102, MR103, MR104, MR107

Testing Frequency Plan due 60 days after Initial Performance Test for

particulate matter, nitrogen oxide, opacity and

carbon monoxide emission limits required by

PSD modeling. The plan shall specify a

testing frequency using the test data based on

MPCA guidance. Future performance tests

based on year (12 month), 36 month, and 60

month intervals, or as applicable, shall be

required on written approval of MPCA per

Minn. R. 7017.2020, subp. 1.

EU001, EU002
TABLE B: RECURRENT SUBMITTALS

Facility Name: Minnesota Power Inc - Hibbard Renewable Energy Ctr

Permit Number: 13700015 - 004

B-3 12/23/09

What to send When to send Portion of Facility Affected

Excess Emissions/Downtime Reports (EER's) due 30 days after end of each calendar

quarter starting 07/14/1997 (Submit

Deviations Reporting Form DRF-1). The EER

shall indicate all periods of exceedances of

the limit including exceedances allowed by an

applicable standard, i.e. during startup,

shutdown, and malfunctions.

MR101, MR102, MR103, MR104

Linearity Test Results Summary due 30 days after end of each calendar

quarter following Linearity and Leak Check

Test (Acid Rain Program) if performed.

MR101, MR102, MR103, MR104, MR107

Relative Accuracy Test Audit (RATA) Results

Summary

 due 30 days after end of each calendar

quarter following CEMS Relative Accuracy

Test Audit (RATA) .

MR101, MR102, MR103, MR104, MR107

Semiannual Deviations Report due 30 days after end of each calendar

half-year starting 03/14/2002 . A mid-year

report, covering deviations which occurred

during the period from January 1 through June

30, is due by July 30 of each year. An

end-of-year report, covering deviations which

occurred during the period from July 1 through

December 31, is due by January 30 of each

year. The report must be submitted even if

there were no deviations for the reporting

period. To be submitted on a form approved

by the Commissioner.

Total Facility

Compliance Certification due 30 days after end of each calendar year

starting 03/14/2002 (for the previous calendar

year). To be submitted on a form approved by

the Commissioner.

Total Facility

APPENDIX MATERIAL 

Minnesota Power Inc – Hibbard Renewable Energy Center 

Appendix I – Insignificant Activities 

Appendix II – Phase II Permit Application (federal Acid Rain regulations) 

Appendix I – Insignificant Activities 

Coal unloading 

Coal bunker to coal transfer 

Fuel oil storage tank 

Analysis laboratory 

Welding 

Parts washer 

Natural gas vents 

Propane space heating 

Ash handling 

 

These activities must be listed more specifically in the permit application (and the permit), if any of the 

following are true: 

1) the emissions units are subject to additional requirements under Section 114(a)(3) of the 

Clean Air Act (CAM); 

2) the emissions units are subject to Hazardous Air Pollutant requirements under Section 112 of 

the Clean Air Ac (part 63 NESHAPs); 

3) the emissions units are part of a Title I modification (NSR, pt 61 or 63 NESHAP mods, or 

NSPS mod); 

4) if accounted for, the emissions units make the stationary source subject to a part 70 permit; 

or 

5) the unit is required to do periodic monitoring. 

If none of the above are true, the activity can be listed in a general way in the permit with its applicable 

requirements (per White Paper Number 2). Make sure the TSD addresses why no periodic monitoring is 

necessary per September 1998 guidance on periodic monitoring. 

The following table lists likely applicable requirements for subpart 3 insignificant activities (IAs). It is 

assumed that subpart 2 IAs are consistent with EPA’s “trivial” activity list and “may be presumptively 

omitted from part 70 applications” per White Paper Number 1. Subpart 4 IAs would need to be included 

in the permit as well, but can not easily be addressed generically. So, they are not listed below. 

Insignificant Activities and Applicable Requirements

Under Minn. R. 7007.1250, subp. 1(A), the Permittee may add insignificant activities to the stationary 

source throughout the term of the permit without getting permit amendments. Certain exclusions apply 

and are listed in Minn. R. 7007.1250, subp.2. In addition, this permit specifically prohibits the Permittee 

from making any modifications that would make the source major under NSR. The following table is a 

listing of the insignificant activities that the Permittee is somewhat likely to add and their associated 

applicable requirements. 

Minn. R. 

7007.1300, 

subpart 

Rule Description of the Activity Applicable Requirement 

3(A) Fuel use: space heaters fueled by, kerosene, natural gas, or 

propane. 

Minn. R. 7011.0510/0515 

3(B) Furnaces, boilers, and incinerators: 

nfrared electric ovens; and Minn. R. 7011.0105/0110 

fuel burning equipment with a capacity less than 500,000 

Btu/hour but only if the total combined capacity of all fuel 

burning equipment at the stationary source with a capacity 

less than 500,000 Btu per hour is less than or equal to 

2,000,000 Btu/hour. 

Minn. R. 7011.0510/0515 OR 

Minn. R. 7011.0610 +

Minn. R. 7011.1215, subp. 3 (if 

pathwaste combustor)

3(C) fabrication operations: equipment used exclusively for forging, 

pressing, drawing, spinning, or extruding hot metals. 

Minn. R. 7011.0710/0715 

3(D) Processing operations: 

open tumblers with a batch capacity of 1,000 pounds or less; 

and 

Minn. R. 7011.0710/0715 

3(E) Storage tanks: 
Minn. R. 

7007.1300, 

subpart 

Rule Description of the Activity Applicable Requirement 

1. gasoline storage tanks with a combined total tankage 

capacity of not more than 10,000 gallons; and 

Minn. R. 7011.0710/0715 OR 

Minn. R. 7011.1505, subp. 2(B)/1505, 

subp. 3(B) OR 

Minn. R. 7011.0105/0110 (if not 

associated with industrial process per 

the IPE definition)

2. non-hazardous air pollutant VOC storage tanks with a 

combined total tankage capacity of not more than 10,000 

gallons of non-hazardous air pollutant VOCs and with a 

vapor pressure of not more than 1.0 psia at 60 degrees 

Fahrenheit. 

Minn. R. 7011.0710/0715 OR

Minn. R. 7011.1505, subp. 2(B)/1505, 

subp. 3 (B)

OR Minn. R. 7011.0105/0110 (if not 

associated with industrial process per 

the IPE definition)

3(F) Cleaning operations: commercial laundries, not including dry 

cleaners and industrial launderers. 

Minn. R. 7011.0105/0110 

3(G) Emissions from a laboratory, as defined in the subpart. Minn. R. 7011.0510/0515 + 

Minn. R. 7011.0610 + Minn. R. 

7011.0710/0715 

3(H) Miscellaneous: 

1. equipment used exclusively for packaging lubricants or 

greases; 

Minn. R. 7011.0710/0715 OR Minn. 

R. 7011.0105/0110 

2. equipment used for hydraulic or hydrostatic testing; Minn. R. 7011.0710/0715 

3. brazing, soldering or welding equipment; Minn. R. 7011.0510/.0515 + 

Minn. R. 7011.0610 + Minn. R. 

7011.0710/0715 

4. blueprint copiers and photographic processes; Minn. R. 7011.0105/0110 

5. equipment used exclusively for melting or application of 

wax; 

Minn. R. 7011.0510/.0515 + 

Minn. R. 7011.0610 + Minn. R. 

7011.0710/0715 

6. nonasbestos equipment used exclusively for bonding 

lining to brake shoes; and 

Minn. R. 7011.0710/0715 

7. cleaning operations: alkaline/phosphate cleaners and 

associated cleaners and associated burners. 

Minn. R. 7011.0510/.0515 + 

Minn. R. 7011.0610 + Minn. R. 

7011.0710/0715 

3(I) Individual emissions units at a stationary source, each of 

which have a potential to emit the following pollutants in 

amounts less than: 

1. 4,000 lbs/year of carbon monoxide; and 

2. 2,000 lbs/year each of nitrogen oxide, sulfur dioxide, 

particulate matter, particulate matter less than ten microns, 

Case-by-case determination 
Minn. R. 

7007.1300, 

subpart 

Rule Description of the Activity Applicable Requirement 

volatile organic compounds (including hazardous air 

pollutant-containing VOC), and ozone. 

3(J) Fugitive Emissions from roads and parking lots. Minn. R. 7011.0150 

3(K) Infrequent use of spray paint equipment for routine 

housekeeping or plant upkeep activities not associated with 

primary production processes at the stationary source, such 

as spray painting of buildings, machinery, vehicles, and 

other supporting equipment. 

Minn. R. 7011.0710/0715 

Insignificant Activities Required to Be Listed for Part 70 sources

Minn. R. 

7007.1300, 

subpart 

Rule Description of the Activity Applicable Requirement 

4 Individual emissions units at a stationary source, each of 

which has: 

A. Potential emissions of 5.7 pounds per hour or actual 

emissions of two tons per year of carbon monoxide; 

B. Potential emissions of 2.28 pounds per hour or actual 

emissions of one ton per year for particulate matter, 

particulate matter less than ten microns, nitrogen oxide, 

sulfur dioxide, and VOCs; and 

C. For hazardous air pollutants, emissions units with: 

(1) potential emissions of 25 percent or less of the 

hazardous air pollutant thresholds listed in subp. 5; or 

(2) combined HAP actual emissions of one ton per year 

unless the emissions unit emits one or more of the HAPs 

listed in this subpart. 

Conditionally Insignificant Activities 

Rule Description of the Activity Applicable Requirement 

Minn. R. 

7008.4100 

Total VOC Usage at the stationary source less than 200 

gallons or 2000 pounds in each calendar year. See Minn. R. 

7008.4100 for recordkeeping and calculation requirements 

for this activity. 

Minn. R. 7011.0710/0715 

Minn. R. 

7008.4110

Emissions from equipment venting particulate matter (PM) or 

particulate matter less than 10 microns (PM-10) inside a 

building, provided that emissions from the equipment are: 

a). filtered through an air cleaning system; and 

b). vented inside of the building 100% of the time. 

Minn. R. 7011.0710/0715 

Appendix II – Phase II Permit Application (federal Acid Rain regulations) 
Acrobat Document
Technical Support Document, Permit Action Number: 13700015-004 

Page 1 of 3 

Date: 12/24/2009 

TECHNICAL SUPPORT DOCUMENT

For 

AIR EMISSION PERMIT NO. 13700015 - 004

This technical support document (TSD) is intended for all parties interested in the permit and to meet the 

requirements that have been set forth by the federal and state regulations (40 CFR § 70.7(a)(5) and Minn. 

R. 7007.0850, subp. 1). The purpose of this document is to provide the legal and factual justification for 

each applicable requirement or policy decision considered in the determination to issue the permit. 

1. General Information

1.1 Applicant and Stationary Source Location 

Table 1. Applicant and Source Address 

Applicant/Address Stationary Source/Address 

(SIC Code: 4961/4911) 

Minnesota Power 

30 West Superior Street 

Duluth, MN 55807 

Minnesota Power – Hibbard Renewable Energy Center 

4913 Main St 

Duluth 

St. Louis County 

Contact: Melissa Weglarz 

Phone: 218.355.3321 

1.2 Facility Description 

The Hibbard Renewable Energy Center steam and power generating facility was jointly owned by 

Minnesota Power (MP) and the City of Duluth. Boilers 3 & 4 and their associated equipment were owned 

by the City of Duluth, whereas MP owned the remaining portion of the facility. The facility is located in 

the City of Duluth, adjacent to the NewPage paper mill. The facility combusts a mixture of wood, coal, 

natural gas and paper mill sludge. The primary mission of the facility is to produce steam for NewPage 

and its associated paper recycling facility. The facility is also capable of producing electrical energy for 

the MP system. The site contains four steam generating boilers, four steam turbines, coal handling 

facilities, wood handling facilities, a 3.4 million gallon fuel oil storage tank and natural gas supply lines. 

The two oldest boilers and their associated turbine-generators (Boilers No. 1 and No. 2), and the fuel oil 

supply tank have been out of service since 1981, but can be used if future plans were to change. 

All operations and equipment within the facility boundary are established to: (1) provide steam and/or 

electrical power for on-site and off-site utilization; (2) provide fuel for steam and/or electrical power 

production or support activities; (3) monitor and control air emissions generated from electrical power 

production; (4) handle waste heat, wastes and materials produced from the on-site operations; and (5) 

provide support activities. These operations and equipment are described below. 

Steam and Power Generation

Steam and power generation is accomplished primarily through steam generation in two boilers (Boilers 

No. 3 and No. 4). Both units have spreader stokers and traveling grates. Emissions are discharged through 

a common 331 foot stack (Stack No. 1). Boilers No. 1 and No. 2 are smaller units and if used would also 

discharge air emissions through Stack No. 1. 

Fuel for Steam and Power Generation and Support Equipment/Activities
Technical Support Document, Permit Action Number: 13700015-004 

Page 2 of 3 

Date: 12/24/2009 

Boilers No. 3 and No. 4 are capable of combusting a mixture of wood, sub-bituminous coal, natural gas 

and sludge. The primary fuel is wood which may include wood chips, sawdust, sander dust, wood bark, 

chipped railroad ties and other various forms of waste wood from regional suppliers. The wood fuel is 

supplemented with low-sulfur, sub-bituminous coal and natural gas. Boilers No. 3 and No. 4 are capable 

of combusting wood, coal, and various combinations of wood, coal, and natural gas. This permit allows 

for the addition of oily coal (coal with oil spilled on it), oily cellulose-based sorbents (including rags), 

activated charcoal, boiler cleaning agents, and cellulose fill from mattress recycling as permitted fuels. 

The wood fuel is delivered directly to the plant in covered trucks, unloaded and conveyed directly to the 

A-frame storage building. The wood fuel is conveyed to the wood metering bins and transferred to the 

boiler’s traveling grate through the auger feed and spreader stoker systems. Combustion occurs in 

suspension and on the grate. 

Coal is delivered to the facility in trucks and unloaded in a three sided enclosure maintained at negative 

pressure and vented through a fabric filter. Coal is transferred from the unloading facility to storage 

bunkers by a bucket conveyor system. Air from the bunkers and coal transfer system is vented through a 

fabric filter. Coal transfer from the bunker to the boilers is accomplished by a totally enclosed conveyor. 

Natural gas is supplied to Boilers No. 3 and No. 4 through a pipeline. Natural gas could be supplied to 

Boilers No. 1 and No. 2 by the same system. 

If used in the future as fuel, oil would be delivered by truck and stored in the 3.4 million gallon tank. 

Piping which would connect the fuel oil storage to the boilers is disconnected. 

Air Emission Monitoring and Control

Air emissions from the facility are released primarily as a result of the combustion of wood and coal. 

Smaller amounts of criteria pollutants are emitted from the combustion of natural gas and the handling 

and storage of coal and wood fuels. The combustion of wood and coal also results in the emission of some 

hazardous air emissions. 

Continuous Emission Monitors have been installed, tested and certified to measure and record the 

combustion emissions from Boilers No. 3 & No. 4 exiting via the common stack, Stack 

No. 1. The monitors measure and record information on the following parameters: Sulfur Dioxide, 

Nitrogen Oxides, opacity, Carbon Monoxide, Carbon Dioxide, and volumetric flow and are located in the 

breaching leading to the stack. 

Particulate emissions from Stack No. 1 due to combustion in Boilers No. 3 and No. 4 are controlled by 

multiple cyclones in series with an electrostatic precipitator for each unit. Boilers No. 1 and 

No. 2 do not have associated pollution control equipment. Particulates from coal unloading, transfer, and 

storage are controlled with fabric filter baghouses. Additional particulate control is accomplished through the 

use of enclosures to limit fugitive emissions from coal and wood unloading operations. 

Waste Heat, Wastes, and Materials 

The facility is designed to operate with a once-through cooling system to dissipate waste heat in the 

production of electrical energy. Water from St. Louis Bay is pumped through the intake structure, used to 

condense steam from the back side of the turbine generator and discharged to the bay. 
Technical Support Document, Permit Action Number: 13700015-004 

Page 3 of 3 

Date: 12/24/2009 

The combustion of wood and coal also produces ash, which is collected off the traveling grates, wetted and 

transferred to a truck. The ash is used as agricultural soil enhancement or is landfilled. 

Support Activities

Support activities include the building elevator, vehicle maintenance, general facility activities, energy 

production equipment maintenance, piping installation and maintenance. These activities can include 

painting, welding, and cleaning operations. In terms of air emission regulations, these activities are 

considered insignificant activities for these purposes. 

1.3 Description of Changes Made through this Permit Action 

This administrative amendment (Permit Action 004) is for a change in ownership of the facility. The 

Hibbard Energy Center is owned and operated by Minnesota Power, due to purchasing the City of 

Duluth’s portion of the facility. This amendment was initiated through an administrative amendment 

application received by MPCA on August 18, 2008, with supplemental information received October 15, 

2009. This change is made in accordance with Minn. R. 7007.1400, subp. 1(E). 

Stora Enso North America paper mill was purchased by NewPage. Therefore, references to Stora Enso 

North America in the permit have been replaced with NewPage Duluth Paper Mill. 

Other updates to the permit to reflect current MPCA policy: 

• A recordkeeping requirement that applies to major HAPs sources was added. 

• A recordkeeping requirement was added for changes not requiring a permit amendment. 

• Since the permit has appendices, a requirement to comply with appendices was added. 

• The Delta facility description for control equipment has been updated. 

1.4. Facility Emissions 

There are no emissions increases associated with this permit action. 

2. Conclusion

Based on the information provided by Minnesota Power, the MPCA has reasonable assurance that the 

proposed operation of the emission facility, as described in the Air Emission Permit No. 13700015-004 

and this TSD, will not cause or contribute to a violation of applicable federal regulations and Minnesota 

Rules. 

Staff Members on Permit Team: Sarah Sevcik (permit writer/engineer) 

Steve Palzkill (enforcement) 

Tarik Hanafy (peer reviewer) 

AQ File No. 73A; DQ # 2199, 2873 

Attachments: Facility Description and CD-01 Forms 

OMB 2060-0631 Part I Question 14a

Minnesota Power Hibbard Renewable Energy Center (1897)Materials listed in the permitHIBBARD "Other" Materials permitted to burn Permitted to burn

Actually 

burn? 

(Yes/No)

Quantity / 

year

Unit 3 Wood, including creosoted railroad ties 67 tons per hour, also must comply with heat input restrictions yes 106,294 Unit 4 Wood, including creosoted railroad ties 67 tons per hour, also must comply with heat input restrictions yes 106,294 

Hardboard Rejects / Waste wood (consisting of rejects and/or trimmings consisting primarily of wood with some glues and/or adhesives and backings)

up to 28,500 tons yes 1,188 

Sludge from NewPage Duluth Paper Mill clarifier NA yes 7,500 Oily cellulose-based sorbents (including oily rags) NA yes >1 Oily coal and oily wood (coal or wood with oil spilled on it) NA yes >1 Boiler cleaning agents (must be EDTA type or Ammonium Bromate, and agents generated on-site)

Maximum of 5% of total fuel mass input, oxygen must be 3% or greater, and agents may be burned only while the boiler is operating at 75 percent of rated capacity or greater.

no - 

Activated charcoal NA yes 12 

Cellulose fill from mattress recycling NA no - 

NA = No numerical limit specifically listed in permit, however permit contains complicated formulas for appropriating emissions due to each fuel type

U3&4 

combined

If "other" was checked in questions 10 or 11 above indicating that any non-fossil fuel or other material (including, but not limited to, plastics, treated wood, rubber belting or gaskets, whole solutions, animal wastes, etc.) is either utilized or permitted to be used, please indicate below what materials are combusted in the boiler and in what quantities (specify whether this qua[Btu] basis). Also indicate (yes/no) whether you are permitted to burn non-fossil fuel(s) or other material(s) even if you do not actually burn them. 
1

23456789

101112131415161718192021222324252627282930313233

A B C D E F 

OMB 2060-0631 Part I, Question 15: Identification (or designation) of all coal- and oil-fired steam generating units (boilers) (as defined by Clean Air Act section 1

Minnesota Power Hibbard Renewable Energy Center (1897)

Facility Name

Subpart EIA Plant CodeQ 15.01 Boiler ID Unit 3 Unit 4Q 15.02 Original design fuel (i.e. coal rank or type of oil) Waste wood, coal, and natural gas2 Waste wood, coal, and natural gas2

Q 15.03 Design heat input (mmBtu/hr)1 590 590

Q 15.04 Present maximum heat input, (mmBtu/hr)3 518 471Q 15.05 MWe gross capacity summer 35 36Q 15.06 MWe net capacity summer 33 34Q 15.07 Original design gross efficiency (%, HHV)Q 15.08 Present operating gross efficiency (%, HHV)4 NA NA

Q 15.09 Design steam pressure (psig)1 925 925

Q 15.10 Operating steam pressure (psig) 835 835Q 15.11 Design steam temperature (°F)1 750 750Q 15.12 Operating steam temperature (°F) 725 725Q 15.13 Design steam reheat temperature (°F)5 NA NA

Q 15.14 Operating steam reheat temperature (°F)5 NA NAQ 15.15 FuelQ 15.16 Hours/year operated 6951 6628.33Q 15.17 Average annual capacity factor for the past 3 years 20.04 01.0Q 15.18 Applicable NSPS Subpart Db Subpart DbQ 15.19 Estimated year of retirement Minnesota Power has no scheduled or planned retirement dates for any of our units

1Original design values based on boiler acquisition contracts and/or heat balance drawings. For Hibbard, these values are the retrofitted condition. Design heat inp

Design heat input and present maximum heat input are based on blend of the different fuels. 

2All Hibbard units were originally built as bituminous coal-fired units and later retrofitted to burn waste wood, coal, & natural gas.3Current heat input data from Title V permit application does not represent maximum heat input capacity. We do not partition heat input measurements/calculations 4We do not measure or calculate boiler efficiency on either unit at this facility. 5Units do not have a reheat cycle

33% coal, 60% wood, 7% gas, <1% other

73.4 on wood (4400btu/lb), coal (8600btu/lb), gas (1000btu/scf)

HIBBARD

1897

67.7 on wood (4400 btu/lb)
OMB 2060-0631 Part I, Question 16: Emission Control Technology

Minnesota Power Hibbard Renewable Energy Center (1897)Designate the order of the emission controls -- 1 for first control following the boiler, 2 for second control following the boiler, etc.

Plant ID Boiler ID Type NOx Control In-service Date SO2 Control In-service Date PM Control In-service Date 

Hibbard 3 Stoker fired 1 - Low NOx Burners, when firing gas controlled combustion techniques 1987 Low sulfur PRB coal 1987 2 - Mechanical Dust Collector, 3 - ESP 1949, 1987 

1897 4 Stoker-fired 1 - Low NOx Burners, when firing gas controlled combustion techniques 1987 Low sulfur PRB coal 1987 2 - Mechanical Dust Collector, 3 - ESP 1951, 1987 
OMB 2060-0631 Part I Question 22: Guaranteed Emission Rate

Minnesota Power Hibbard Renewable Energy Center (1897)

PM PM10 PM2.5 SO2 HCl and/or HF HCN Metal HAP Hg CO 

1 0.1 lbs/mmBtu or 99%2 0.1 lbs/mmBtu or 99%

Hibbard

Mostrecent guaranteed emission rate for each pollutant for which there is a permitted emission limit

Plant ID Boiler ID
OMB 2060-063 Part II Questions 2-3

Coal Shipments - Minnesota Power Hibbard Renewable Energy Center (1897)

date_delivered tons Boiler ID# State County Coal Seam

Fuel Ship 

Method Sulfur % Ash % BTU/lb Mercury Chlorine F

01-Jan-09 360.68 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

02-Jan-09 538.92 3,4 MT Big Horn Anderson Dietz TR 3.50 0.27 9,303.00 N/A N/A N03-Jan-09 474.85 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N04-Jan-09 487.97 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N05-Jan-09 702.41 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N06-Jan-09 403.03 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N07-Jan-09 301.83 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N08-Jan-09 398.96 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N09-Jan-09 297.85 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N10-Jan-09 462.30 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N11-Jan-09 471.87 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N12-Jan-09 249.49 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N13-Jan-09 502.15 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N14-Jan-09 400.59 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N15-Jan-09 508.92 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N16-Jan-09 452.90 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N17-Jan-09 222.22 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N18-Jan-09 140.36 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N19-Jan-09 111.03 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N20-Jan-09 56.06 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N21-Jan-09 340.13 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N22-Jan-09 84.85 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N23-Jan-09 194.72 3,4 MT Big Horn Anderson Dietz TR 4.22 0.33 9,254.00 N/A N/A N

24-Jan-09 112.59 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N25-Jan-09 57.52 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N26-Jan-09 27.27 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N27-Jan-09 239.96 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N28-Jan-09 106.55 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N29-Jan-09 494.62 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N30-Jan-09 301.70 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N31-Jan-09 198.47 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

01-Feb-09 82.06 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

02-Feb-09 285.72 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

03-Feb-09 369.54 3,4 MT Big Horn Anderson Dietz TR 5.32 0.33 8,984.00 N/A N/A N

04-Feb-09 314.20 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

05-Feb-09 396.14 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

06-Feb-09 230.73 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

07-Feb-09 230.67 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

08-Feb-09 82.98 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

09-Feb-09 57.76 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

10-Feb-09 140.18 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

11-Feb-09 171.67 3,4 MT Big Horn Anderson Dietz TR 3.95 0.31 9,076.00 N/A N/A N

12-Feb-09 198.98 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N
13-Feb-09 56.36 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

14-Feb-09 57.36 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

15-Feb-09 81.91 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

16-Feb-09 54.54 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

17-Feb-09 55.75 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

18-Feb-09 55.89 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

19-Feb-09 55.26 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

20-Feb-09 111.51 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

21-Feb-09 27.73 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

22-Feb-09 27.29 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

23-Feb-09 222.17 3,4 MT Big Horn Anderson Dietz TR 3.15 0.18 9,449.00 N/A N/A N

24-Feb-09 142.43 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

26-Feb-09 27.76 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

27-Feb-09 54.25 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

28-Feb-09 251.01 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

01-Mar-09 198.49 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

02-Mar-09 197.67 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

03-Mar-09 169.20 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

04-Mar-09 57.65 3,4 MT Big Horn Anderson Dietz TR 4.74 0.35 8,787.00 N/A N/A N

05-Mar-09 224.48 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

06-Mar-09 143.42 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

07-Mar-09 227.55 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

08-Mar-09 113.66 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

09-Mar-09 184.78 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

10-Mar-09 136.69 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

11-Mar-09 245.28 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

12-Mar-09 215.43 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

13-Mar-09 215.82 3,4 MT Big Horn Anderson Dietz TR 3.63 0.34 9,313.00 N/A N/A N

14-Mar-09 132.92 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

15-Mar-09 137.46 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

16-Mar-09 138.66 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

17-Mar-09 138.31 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

18-Mar-09 96.89 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

19-Mar-09 219.80 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

20-Mar-09 269.80 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

24-Mar-09 219.30 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

25-Mar-09 294.32 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

26-Mar-09 197.32 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

27-Mar-09 224.44 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

28-Mar-09 150.08 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

29-Mar-09 222.68 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

30-Mar-09 245.31 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

31-Mar-09 381.73 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

01-Apr-09 382.60 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

02-Apr-09 165.84 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

03-Apr-09 188.91 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

04-Apr-09 142.52 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

05-Apr-09 168.32 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N
06-Apr-09 219.05 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

07-Apr-09 195.21 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

08-Apr-09 169.48 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

09-Apr-09 147.76 3,4 MT Big Horn Anderson Dietz TR 3.84 0.34 9,224.00 N/A N/A N

10-Apr-09 170.12 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

11-Apr-09 142.72 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

12-Apr-09 143.76 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

13-Apr-09 123.47 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

14-Apr-09 147.38 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

15-Apr-09 169.65 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

16-Apr-09 99.63 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

17-Apr-09 196.52 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

18-Apr-09 73.41 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

19-Apr-09 49.62 3,4 MT Big Horn Anderson Dietz TR 3.74 0.32 9,265.00 N/A N/A N

21-Apr-09 217.76 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

22-Apr-09 96.53 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

23-Apr-09 122.28 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

24-Apr-09 49.29 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

25-Apr-09 122.35 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

26-Apr-09 147.05 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

27-Apr-09 169.26 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

28-Apr-09 71.56 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

29-Apr-09 167.42 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

30-Apr-09 98.03 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

01-May-09 71.56 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

02-May-09 71.49 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N03-May-09 71.85 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N04-May-09 73.13 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N05-May-09 121.41 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N06-May-09 73.13 3,4 MT Big Horn Anderson Dietz TR 4.25 0.33 8,956.00 N/A N/A N

07-May-09 48.92 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

08-May-09 197.77 3,4 MT Big Horn Anderson Dietz TR 4.33 0.35 8,903.00 N/A N/A N

09-May-09 98.59 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

10-May-09 49.38 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N11-May-09 97.46 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N12-May-09 147.18 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N13-May-09 119.34 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N14-May-09 146.59 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N15-May-09 74.34 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N16-May-09 142.12 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N17-May-09 95.84 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N18-May-09 119.35 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N19-May-09 119.61 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N20-May-09 119.28 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N21-May-09 120.07 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N22-May-09 95.81 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N23-May-09 218.02 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N24-May-09 144.64 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N
25-May-09 145.55 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

26-May-09 48.77 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N27-May-09 343.87 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N28-May-09 98.69 3,4 MT Big Horn Anderson Dietz TR 3.03 0.25 9,743.00 N/A N/A N29-May-09 98.21 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N30-May-09 146.31 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N31-May-09 121.02 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

01-Jun-09 96.45 3,4 MT Big Horn Anderson Dietz TR 3.92 0.35 9,359.00 N/A N/A N02-Jun-09 95.77 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N03-Jun-09 119.12 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N04-Jun-09 119.36 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N05-Jun-09 70.66 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N06-Jun-09 122.39 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N07-Jun-09 95.58 3,4 MT Big Horn Anderson Dietz TR 3.83 0.30 9,232.00 N/A N/A N08-Jun-09 143.15 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N09-Jun-09 95.66 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N10-Jun-09 118.98 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N11-Jun-09 72.23 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N12-Jun-09 143.21 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N13-Jun-09 95.37 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N14-Jun-09 48.23 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N15-Jun-09 73.64 3,4 MT Big Horn Anderson Dietz TR 3.42 0.28 9,293.00 N/A N/A N16-Jun-09 98.17 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

17-Jun-09 74.56 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N18-Jun-09 73.13 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N19-Jun-09 73.47 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N20-Jun-09 73.10 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N21-Jun-09 123.79 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N22-Jun-09 119.76 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N23-Jun-09 70.76 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N24-Jun-09 47.34 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N25-Jun-09 143.64 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N26-Jun-09 72.61 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N27-Jun-09 122.78 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N28-Jun-09 171.59 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N29-Jun-09 96.14 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N30-Jun-09 96.18 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

01-Jul-09 144.73 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

02-Jul-09 144.62 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

03-Jul-09 144.68 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

04-Jul-09 96.20 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

05-Jul-09 144.88 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

06-Jul-09 47.64 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

07-Jul-09 97.72 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

08-Jul-09 171.65 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

09-Jul-09 195.12 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

10-Jul-09 149.35 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

11-Jul-09 121.07 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N
12-Jul-09 48.64 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

15-Jul-09 200.74 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

16-Jul-09 173.58 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

17-Jul-09 242.88 3,4 MT Big Horn Anderson Dietz TR 3.98 0.33 9,117.00 N/A N/A N

18-Jul-09 123.55 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

19-Jul-09 122.10 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

20-Jul-09 96.70 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

21-Jul-09 94.88 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

22-Jul-09 94.58 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

23-Jul-09 70.49 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

24-Jul-09 94.22 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

25-Jul-09 142.41 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

26-Jul-09 94.63 3,4 MT Big Horn Anderson Dietz TR 4.41 0.39 9,163.00 N/A N/A N27-Jul-09 97.67 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

28-Jul-09 122.78 3,4 MT Big Horn Anderson Dietz TR 3.78 0.36 9,254.00 N/A N/A N

29-Jul-09 147.21 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

30-Jul-09 49.58 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

31-Jul-09 123.26 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

01-Aug-09 96.57 3,4 MT Big Horn Anderson Dietz TR 3.70 0.32 9,349.00 N/A N/A N

02-Aug-09 99.00 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

03-Aug-09 97.25 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

04-Aug-09 72.99 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

05-Aug-09 168.18 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

06-Aug-09 49.83 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

07-Aug-09 121.31 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

09-Aug-09 161.99 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

10-Aug-09 165.39 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

11-Aug-09 70.98 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

12-Aug-09 70.93 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

13-Aug-09 95.19 3,4 MT Big Horn Anderson Dietz TR 4.39 0.31 9,204.00 N/A N/A N

14-Aug-09 46.56 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

15-Aug-09 70.84 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

16-Aug-09 94.68 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

17-Aug-09 122.84 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

18-Aug-09 74.60 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

19-Aug-09 98.52 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

20-Aug-09 146.01 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

21-Aug-09 98.62 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

22-Aug-09 98.77 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

23-Aug-09 73.87 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

24-Aug-09 72.38 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

25-Aug-09 97.38 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

26-Aug-09 24.17 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

27-Aug-09 118.37 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

28-Aug-09 95.95 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

29-Aug-09 165.75 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

30-Aug-09 72.68 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

31-Aug-09 118.81 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N
01-Sep-09 71.19 3,4 MT Big Horn Anderson Dietz TR 4.30 0.30 8,983.00 N/A N/A N

02-Sep-09 118.72 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

03-Sep-09 94.09 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

04-Sep-09 164.57 3,4 MT Big Horn Anderson Dietz TR 4.45 0.30 9,296.00 N/A N/A N

05-Sep-09 118.79 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

06-Sep-09 94.33 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

07-Sep-09 74.00 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

08-Sep-09 99.50 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

09-Sep-09 49.18 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

10-Sep-09 98.43 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

11-Sep-09 98.07 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

12-Sep-09 121.64 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

13-Sep-09 73.76 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

14-Sep-09 97.37 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

15-Sep-09 73.97 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

16-Sep-09 121.98 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

17-Sep-09 144.89 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

18-Sep-09 73.99 3,4 MT Big Horn Anderson Dietz TR 4.67 0.27 8,970.00 N/A N/A N

19-Sep-09 120.33 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

20-Sep-09 70.47 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

21-Sep-09 262.95 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

22-Sep-09 262.87 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

23-Sep-09 266.17 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

24-Sep-09 265.81 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

25-Sep-09 143.72 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

26-Sep-09 120.33 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

27-Sep-09 122.18 3,4 MT Big Horn Anderson Dietz TR 4.31 0.30 10,072.00 N/A N/A N

28-Sep-09 220.55 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

29-Sep-09 197.69 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

30-Sep-09 247.46 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

01-Oct-09 293.23 3,4 MT Big Horn N/A TR N/A N/A N/A N/A N/A N

02-Oct-09 144.59 3,4 MT Big Horn N/A TR N/A N/A N/A N/A N/A N

03-Oct-09 146.56 3,4 MT Big Horn N/A TR N/A N/A N/A N/A N/A N

04-Oct-09 97.51 3,4 MT Big Horn N/A TR N/A N/A N/A N/A N/A N

05-Oct-09 70.77 3,4 MT Big Horn N/A TR N/A N/A N/A N/A N/A N

06-Oct-09 170.38 3,4 MT Big Horn N/A TR N/A N/A N/A N/A N/A N

07-Oct-09 291.62 3,4 MT Big Horn N/A TR N/A N/A N/A N/A N/A N

08-Oct-09 245.50 3,4 MT Big Horn N/A TR N/A N/A N/A N/A N/A N

09-Oct-09 223.56 3,4 MT Big Horn N/A TR N/A N/A N/A N/A N/A N

10-Oct-09 221.06 3,4 MT Big Horn N/A TR N/A N/A N/A N/A N/A N

11-Oct-09 240.88 3,4 MT Big Horn N/A TR 4.14 0.31 8,923.00 N/A N/A N

12-Oct-09 217.11 3,4 MT Big Horn N/A TR N/A N/A N/A N/A N/A N

13-Oct-09 170.02 3,4 MT Big Horn N/A TR N/A N/A N/A N/A N/A N

14-Oct-09 167.29 3,4 MT Big Horn N/A TR N/A N/A N/A N/A N/A N

15-Oct-09 118.21 3,4 MT Big Horn N/A TR N/A N/A N/A N/A N/A N

16-Oct-09 71.13 3,4 MT Big Horn N/A TR 5.09 0.32 9,177.00 N/A N/A N

17-Oct-09 141.70 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

18-Oct-09 117.83 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N
19-Oct-09 99.19 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

20-Oct-09 390.65 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

21-Oct-09 196.64 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

22-Oct-09 364.36 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

23-Oct-09 316.88 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

24-Oct-09 266.02 3,4 MT Big Horn Anderson Dietz TR 4.09 0.31 8,879.00 N/A N/A N

25-Oct-09 245.98 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

26-Oct-09 291.08 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

27-Oct-09 222.98 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

28-Oct-09 146.50 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

29-Oct-09 221.46 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

30-Oct-09 266.24 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

31-Oct-09 171.73 3,4 MT Big Horn Anderson Dietz TR 3.75 0.29 8,655.00 N/A N/A N

01-Nov-09 332.06 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

02-Nov-09 385.09 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

03-Nov-09 288.27 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

04-Nov-09 459.57 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

05-Nov-09 335.32 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

06-Nov-09 286.62 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

07-Nov-09 265.55 3,4 MT Big Horn Anderson Dietz TR 3.91 0.31 9,928.00 N/A N/A N

08-Nov-09 287.85 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

09-Nov-09 340.10 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

10-Nov-09 268.75 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

11-Nov-09 392.60 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

12-Nov-09 291.31 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

13-Nov-09 121.68 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

14-Nov-09 170.81 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

15-Nov-09 147.15 3,4 MT Big Horn Anderson Dietz TR 4.04 0.09 8,969.00 N/A N/A N

16-Nov-09 191.31 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

17-Nov-09 238.11 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

18-Nov-09 263.11 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

19-Nov-09 336.25 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

20-Nov-09 261.74 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

21-Nov-09 238.03 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

22-Nov-09 263.38 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

23-Nov-09 313.83 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

24-Nov-09 412.95 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

25-Nov-09 457.70 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

26-Nov-09 387.24 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

27-Nov-09 439.11 3,4 MT Big Horn Anderson Dietz TR 4.09 0.34 9,233.00 N/A N/A N

28-Nov-09 315.31 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

29-Nov-09 265.44 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

30-Nov-09 320.69 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

01-Dec-09 218.89 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

02-Dec-09 537.33 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

03-Dec-09 537.08 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

04-Dec-09 363.65 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

05-Dec-09 310.49 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N
06-Dec-09 219.73 3,4 MT Big Horn Anderson Dietz TR 3.50 0.29 9,118.00 N/A N/A N

07-Dec-09 408.86 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

08-Dec-09 477.91 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

09-Dec-09 261.63 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

10-Dec-09 476.22 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

11-Dec-09 543.44 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

12-Dec-09 357.82 3,4 MT Big Horn Anderson Dietz TR 3.67 0.31 9,110.00 N/A N/A N

13-Dec-09 281.33 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

14-Dec-09 438.56 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

15-Dec-09 442.41 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

16-Dec-09 496.75 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

17-Dec-09 252.05 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

18-Dec-09 109.24 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

19-Dec-09 82.19 3,4 MT Big Horn Anderson Dietz TR 4.68 0.33 9,139.00 N/A N/A N

20-Dec-09 222.73 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

21-Dec-09 223.49 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

22-Dec-09 285.80 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

23-Dec-09 480.74 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

24-Dec-09 358.93 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

25-Dec-09 298.12 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

26-Dec-09 418.08 3,4 MT Big Horn Anderson Dietz TR 4.66 0.36 9,369.00 N/A N/A N

27-Dec-09 512.12 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

28-Dec-09 560.07 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

29-Dec-09 471.53 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

30-Dec-09 509.85 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

31-Dec-09 387.30 3,4 MT Big Horn Anderson Dietz TR N/A N/A N/A N/A N/A N

Oil Shipments - Hibbard Energy Center

OMB 2060-063 Part II Questions 2-3

ID Gallons Boiler ID# State County Coal Seam

Fuel Ship 

Method Sulfur Ash Btu/Lb Mercury Chlorine F

No deliveries of oil received for boiler usage at Hibbard Energy Center.

Fuel Source
OMB 2060-0631 Part II, Question 8a, 8b, 8d

Minnesota Power Hibbard Renewable Energy Center (1897)Boiler ID(as listed in Part I question 15)

Question 8a Emission test report, parametric monitoring data, or other data or monitoring

Question 8b

Date of testing

Question 8b

Type of testing

Question 8b

Constituents

Boiler 3 Pace Analytical

PM and CO Compliance Test

3/19-22/2007 stack PM and CO 

Boiler 4 Pace Analytical

PM and CO Compliance Test

3/15-16/2007 stack PM and CO 
OMB 2060-0631 Part II, Question 12 EPA NESHAPS ICR - Responses prepared by Dale Kreager

Minnesota Power Hibbard Renewable Energy Center (1897)

Boiler ID Test Date PM* SO2 HCL/HF/HCN Metal HAP Hg CO Other organic

Unit Load 

(MW)

Net 

MWH NET)

Moisture

(%) Flow

(dscfm or Nm3/hr)

Flue gas oxygen

(%, dry) Flue gas CO2 (%, dry)

Flue gas temp

(oF)

Flue gas pressure

(atm)

Standard temp

(F)

Standard pressure

(atm)

Boiler 3 3/19-22/2007 Test 1 Particulate = 0.022 lb/mmBtu

 CO = 0.18 lb/mmBtu

Test 2 Particulate = 0.022 lb/mmBtu

 CO = 0.13 lb/mmBtu

Test 3 Particulate = 0.014 lb/mmBtu

 CO = 0.15 lb/mmBtu 

Test 1 = 10.9

Test 2 = 14.3

Test 3 = 14.1

Test 1 = 138,500 dscfm

Test 2 = 147,000 dscfm

Test 3 = 142,700 dscfm

Test 1 = 10.5

Test 2 = 12.6

Test 3 = 10.1

Test 1 = 9.4

Test 2 = 8.3

Test 3 = 10.2

Test 1 = 412

Test 2 = 410

Test 3 = 417

Test 1 = 68

Test 2 = 68

Test 3 = 68

Test 1 = 29.92

Test 2 = 29.92

Test 3 = 29.92

Boiler 4 3/15-16/2007 Test 1 Particulate = 0.0061 lb/mmBtu

 CO = 0.14 lb/mmBtu

Test 2 Particulate = 0.0091 lb/mmBtu

 CO = 0.26 lb/mmBtu

Test 3 Particulate = 0.016 lb/mmBtu

 CO = 0.20 lb/mmBtu

Test 4 Particulate = 0.0050 lb/mmBtu

 CO 

Test 1 = 8.9

Test 2 = 11.7

Test 3 = 12.8

Test 4 = 14.9

Test 5 = 13.7

Test 1 = 137,100 dscfm

Test 2 = 140,300 dscfm

Test 3 = 135,900 dscfm

Test 4 = 126,800 dscfm

Test 5 = 125,500 dscfm

Test 1 = 10.5

Test 2 = 11.3

Test 3 = 11.2

Test 4 = 7.4

Test 5 = 8.4

Test 1 = 9.6

Test 2 = 9.4

Test 3 = 9.5

Test 4 = 12.7

Test 5 = 12.0

Test 1 = 454

Test 2 = 464

Test 3 = 465

Test 4 = 478

Test 5 = 472

Test 1 = 68

Test 2 = 68

Test 3 = 68

Test 4 = 68

Test 5 = 68

Test 1 = 29.92

Test 2 = 29.92

Test 3 = 29.92

Test 4 = 29.92

Test 5 = 29.92

* Averaging Time = 3 - 1 hour rounds
TDD (for hearing and speech impaired only): (651) 282-5332 

Printed on recycled paper containing at least 10% fibers from paper recycled by consumers 

AIR EMISSION PERMIT NO. 13700013-006 

IS ISSUED TO

Minnesota Power Division of ALLETE Inc 

MINNESOTA POWER - LASKIN ENERGY CENTER 

5699 Colby Lake Road 

Hoyt Lakes, St. Louis County, MN 55750 

The emission units, control equipment and emission stacks at the stationary source authorized in this 

permit are as described in the following permit application(s): 

Permit Type Application Date 

Total Facility Reissuance 11/14/2001 

Supplemental Information No. 1 7/11/2008 

Supplemental Information No. 2 8/26/2008 

Administrative Amendment 4/6/2007 

Administrative Amendment 5/30/2008 

This permit supersedes Air Emission Permit No. 13700013-005 and authorizes the Permittee to operate the 

stationary source at the address listed above unless otherwise noted in Table A. The Permittee must comply 

with all the conditions of the permit. Any changes or modifications to the stationary source must be 

performed in compliance with Minn. R. 7007.1150 to 7007.1500. Terms used in the permit are as defined in 

the state air pollution control rules unless the term is explicitly defined in the permit. 

Permit Type: Federal; Pt 70/Major for NSR 

Issue Date: November 25, 2008 

Expiration: November 25, 2013 

 All Title I Conditions do not expire. 

 

 Don Smith, P.E. Manager 

 Air Quality Permits Section 

 Industrial Division 

 

 for Brad Moore 

 Commissioner 

 Minnesota Pollution Control Agency 

TABLE OF CONTENTS 

Notice to the Permittee 

Permit Shield 

Facility Description 

Table A: Limits and Other Requirements 

Table B: Submittals 

Table C: not used in this permit 

Appendix A: not used in this permit 

Appendix B: Acid Rain Permit Application 

Appendix C: Insignificant Activities Required to be Listed 

Appendix D: Compliance Assurance Monitoring Plan 

Appendix E: SO2 Modeling Parameters 

Appendix F: NOX and PM10 Modeling Parameters 

NOTICE TO THE PERMITTEE: 

Your stationary source may be subject to the requirements of the Minnesota Pollution Control Agency’s 

(MPCA) solid waste, hazardous waste, and water quality programs. If you wish to obtain information on 

these programs, including information on obtaining any required permits, please contact the MPCA 

general information number at: 

 Metro Area 651-296-6300 

 Outside Metro Area 1-800-657-3864 

 TTY 651-282-5332 

The rules governing these programs are contained in Minn. R. chs. 7000-7105. Written questions 

may be sent to: Minnesota Pollution Control Agency, 520 Lafayette Road North,St. Paul, 

Minnesota 55155-4194. 

Questions about this air emission permit or about air quality requirements can also be directed to the 

telephone numbers and address listed above. 

PERMIT SHIELD:

Subject to the limitations in Minn. R. 7007.1800, compliance with the conditions of this permit shall be 

deemed compliance with the specific provision of the applicable requirement identified in the permit as 

the basis of each condition. 

Subject to the limitations of Minn. R. 7007.1800 and 7017.0100, subp. 2, notwithstanding the conditions 

of this permit specifying compliance practices for applicable requirements, any person (including the 

Permittee) may also use other credible evidence to establish compliance or noncompliance with 

applicable requirements. 

FACILITY DESCRIPTION: 

The Laskin Energy Center is an electric generating facility located near Aurora, Minnesota. This electric 

power facility contains two identical steam generating boilers, coal receiving, handling, and storage 

facilities, and ash handling and storage capabilities. Each boiler has twelve 4 mmBtu/hr natural gas/oilfired ignitors and dry low Nitrogen Oxides (NOX)combustors. Each boiler vents emissions to a highefficiency wet scrubber that discharges to the atmosphere through a common stack. The scrubbers control 

Particulate Matter (PM), Particulate matter smaller than 10 microns (PM10), Sulfur dioxide (SO2), and 

lead. The net generating capacity is 110 megawatts. 

TABLE A: LIMITS AND OTHER REQUIREMENTS 11/25/08

Minnesota Power - Laskin Energy Center

13700013 - 006

Facility Name:

Permit Number:

A-1

Table A contains limits and other requirements with which your facility must comply. The limits are located in the first column of

the table (What To do). The limits can be emission limits or operational limits. This column also contains the actions that you must

take and the records you must keep to show that you are complying with the limits. The second column of Table A (Why to do it)

lists the regulatory basis for these limits. Appendices included as conditions of your permit are listed in Table A under total facility

requirements.

Subject Item: Total Facility

What to do Why to do it

MODELING REQUIREMENTS hdr

Parameters Used in Modeling: The parameters used in the modeling performed for

determining emission and/or operational limits for this facility are listed in Appendix

E of this permit. If the Permittee intends to change any of these parameters, the

Permittee must submit the revised parameters to the Commissioner and receive

written approval before making any changes. The revised parameter information

submittal must include, but is not limited to: the locations, heights and diameters of

the stacks; locations and dimensions of nearby buildings; velocity and temperatures

of the gases emitted; and the emission rates. The plume dispersion characteristics

due to the parameter revisions must equal or exceed the dispersion characteristics

modeled for this permit, and the Permittee shall demonstrate this in the proposal.

Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R.

7007.0100, subps 7A, 7L & 7M; Minn. R. 7007.0800,

subps. 1, 2 & 4; Minn. R. 7009.0010-7009.0080

If the information does not demonstrate equivalent or better dispersion

characteristics, or if a conclusion cannot readily be made about the dispersion, the

Permittee must remodel.

CONTINUED

Parameters Used in Modeling (continued):

For changes that do not involve an increase in an emission rate and that do not

require a permit amendment, the proposal must be submitted as soon as

practicable, but no less than 60 days before making the change to any parameter.

For changes involving increases in emission rates and that require a minor permit

amendment, the proposal must be submitted as soon as practicable, but no less

than 60 days before making the change to any parameter.

For changes involving increases in emission rates and that require a permit

amendment other than a minor amendment, the proposal must be submitted prior

to or with the permit amendment application.

This is a state only requirement and is not enforceable by the EPA Administrator

and citizens under the Clean Air Act.

CONTINUED

DETERMINING IF A PROJECT/MODIFICATION IS SUBJECT TO NEW SOURCE

REVIEW

hdr

These requirements apply where there is a reasonable possibility (as defined in 40

CFR Section 52.21(r)(6)(vi)) that a proposed project, analyzed using the

actual-to-projected-actual (ATPA) test (either by itself or as part of the hybrid test

described in Section 52.21(a)(2)(iv)(f)) and found to not be part of a major

modification, may result in a significant emissions increase. If the ATPA test is not

used for a particular project, or if there is not a reasonable possibility that the

proposed project could result in a significant emissions increase, then these

requirements do not apply to that project.

Even though a particular modification is not subject to New Source Review, or

where there isn't a reasonable possibility that a proposed project could result in a

significant emissions increase, a permit amendment, recordkeeping, or notification

may still be required under Minn. R. 7007.1150 - 7007.1500.

Title I Condition: 40 CFR Section 52.21(r)(6); Minn. R.

7007.3000; Minn. R. 7007.0800, subp. 2

Preconstruction Documentation -- Before beginning actual construction on a

project, the Permittee shall document the following:

1. Project description

2. Identification of any emission unit (EU) whose emissions of an NSR pollutant

could be affected

3. Pre-change potential emissions of any affected existing EU, and the projected

post-change potential emissions of any affected existing or new EU.

4. A description of the applicability test used to determine that the project is not a

major modification for any regulated NSR pollutant, including the baseline actual

emissions, the projected actual emissions, the amount of emissions excluded due

to increases not associated with the modification and that the EU could have

accommodated during the baseline period, an explanation of why the amounts

were excluded, and any creditable contemporaneous increases and decreases that

were considered in the determination.

The Permittee shall maintain records of this documentation.

Title I Condition: 40 CFR Section 52.21(r)(6); Minn. R.

7007.3000; Minn. R. 7007.1200, subp. 4; Minn. R.

7007.0800, subps. 4 & 5
TABLE A: LIMITS AND OTHER REQUIREMENTS 11/25/08

Minnesota Power - Laskin Energy Center

13700013 - 006

Facility Name:

Permit Number:

A-2

The Permittee shall monitor the actual emissions of any regulated NSR pollutant

that could increase as a result of the project and that were analyzed using the

ATPA test, and the potential emissions of any regulated NSR pollutant that could

increase as a result of the project and that were analyzed using potential emissions

in the hybrid test. The Permittee shall calculate and maintain a record of the sum of

the actual and potential (if the hybrid test was used in the analysis) emissions of the

regulated pollutant, in tons per year on a calendar year basis, for a period of 5

years following resumption of regular operations after the change, or for a period of

10 years following resumption of regular operations after the change if the project

increases the design capacity of or potential to emit of any unit associated with the

project.

Title I Condition: 40 CFR Section 52.21(r)(6); Minn. R.

7007.3000; Minn. R. 7007.0800, subps. 4 & 5

Before beginning actual construction of any project which includes any electric

utility steam generating unit (EUSGU), the Permittee shall submit a copy of the

preconstruction documentation (items 1-4 under Preconstruction Documentation,

above) to the Agency.

Title I Condition: 40 CFR Section 52.21(r)(6)(ii); Minn.

R. 7007.3000; Minn. R. 7007.0800, subps. 4 & 5

For any project which includes any EUSGU, the Permittee must submit an annual

report to the Agency, within 60 days after the end of the calendar year. The report

shall contain:

a. The name and ID number of the facility, and the name and telephone number of

the facility contact person

b. The quantified annual emissions analyzed using the ATPA test, plus the

potential emissions associated with the same project analyzed as part of a hybrid

test.

c. Any other information, such as an explanation as to why the summed emissions

differ from the preconstruction projection, if that is the case.

Title I Condition: 40 CFR Section 52.21(r)(6); Minn. R.

7007.3000; Minn. R. 7007.0800, subps. 4 & 5

For any project which does not include any EUSGU, the Permittee must submit a

report to the Agency if the annual summed (actual, plus potential used in hybrid

test) emissions differ from the preconstruction projection and exceed the baseline

actual emissions by a significant amount as listed at 40 CFR Section 52.21(b)(23).

Such report shall be submitted to the Agency within 60 days after the end of the

year in which the exceedances occur. The report shall contain:

a. The name and ID number of the facility, and the name and telephone number of

the facility contact person

b. The annual emissions (actual, plus potential if any part of the project was

analyzed using the hybrid test) for each pollutant for which the preconstruction

projection and significant emissions rate is exceeded.

c. Any other information, such as an explanation as to why the summed emissions

differ from the preconstruction projection.

Title I Condition: 40 CFR Section 52.21(r)(6); Minn. R.

7007.3000; Minn. R. 7007.0800, subps. 4 & 5

OPERATIONAL REQUIREMENTS hdr

The Permittee shall comply with National Primary and Secondary Ambient Air

Quality Standards, 40 CFR pt. 50, and the Minnesota Ambient Air Quality

Standards, Minn. R. 7009.0010 to 7009.0080. Compliance shall be demonstrated

upon written request by the MPCA.

40 CFR pt. 50; Minn. Stat. Section 116.07, subds. 4a &

9; Minn. R. 7007.0100, subps. 7A, 7L & 7M; Minn. R.

7007.0800, subps. 1, 2 & 4; Minn. R.

7009.0010-7009.0080

Circumvention: Do not install or use a device or means that conceals or dilutes

emissions, which would otherwise violate a federal or state air pollution control rule,

without reducing the total amount of pollutant emitted.

Minn. R. 7011.0020

Air Pollution Control Equipment: Operate all pollution control equipment whenever

the corresponding process equipment and emission units are operated, unless

otherwise noted in Table A.

Minn. R. 7007.0800, subp. 2; Minn. R. 7007.0800,

subp. 16(J)

Operation and Maintenance Plan: Retain at the stationary source an operation and

maintenance plan for all air pollution control equipment. At a minimum, the O & M

plan shall identify all air pollution control equipment and control practices and shall

include a preventative maintenance program for the equipment and practices, a

description of (the minimum but not necessarily the only) corrective actions to be

taken to restore the equipment and practices to proper operation to meet applicable

permit conditions, a description of the employee training program for proper

operation and maintenance of the control equipment and practices, and the records

kept to demonstrate plan implementation.

Minn. R. 7007.0800, subps. 14 and 16(J)

Operation Changes: In any shutdown, breakdown, or deviation the Permittee shall

immediately take all practical steps to modify operations to reduce the emission of

any regulated air pollutant. The Commissioner may require feasible and practical

modifications in the operation to reduce emissions of air pollutants. No emissions

units that have an unreasonable shutdown or breakdown frequency of process or

control equipment shall be permitted to operate.

Minn. R. 7019.1000, subp. 4

Fugitive Emissions: Do not cause or permit the handling, use, transporting, or

storage of any material in a manner which may allow avoidable amounts of

particulate matter to become airborne. Comply with all other requirements listed in

Minn. R. 7011.0150.

Minn. R. 7011.0150
TABLE A: LIMITS AND OTHER REQUIREMENTS 11/25/08

Minnesota Power - Laskin Energy Center

13700013 - 006

Facility Name:

Permit Number:

A-3

Noise: The Permittee shall comply with the noise standards set forth in Minn. R.

7030.0010 to 7030.0080 at all times during the operation of any emission units.

This is a state only requirement and is not enforceable by the EPA Administrator or

citizens under the Clean Air Act.

Minn. R. 7030.0010 - 7030.0080

Inspections: The Permittee shall comply with the inspection procedures and

requirements as found in Minn. R. 7007.0800, subp. 9(A).

Minn. R. 7007.0800, subp. 9(A)

The Permittee shall comply with the General Conditions listed in Minn. R.

7007.0800, subp. 16.

Minn. R. 7007.0800, subp. 16

PERFORMANCE TESTING hdr

Performance Testing: Conduct all performance tests in accordance with Minn. R.

ch. 7017 unless otherwise noted in Tables A, B, and/or C.

Minn. R. ch. 7017

Performance Test Notifications and Submittals:

Performance Tests are due as outlined in Tables A and B of the permit. See Table

B for additional testing requirements.

Performance Test Notification (written): due 30 days before each Performance Test

Performance Test Plan: due 30 days before each Performance Test

Performance Test Pre-test Meeting: due 7 days before each Performance Test

Performance Test Report: due 45 days after each Performance Test

Performance Test Report - Microfiche Copy: due 105 days after each Performance

Test

The Notification, Test Plan, and Test Report may be submitted in alternative format

as allowed by Minn. R. 7017.2018.

Minn. Rs. 7017.2030, subp. 1-4, 7017.2018 and Minn.

R. 7017.2035, subp. 1-2

Limits set as a result of a performance test (conducted before or after permit

issuance) apply until superseded as stated in the MPCA's Notice of Compliance

letter granting preliminary approval. Preliminary approval is based on formal review

of a subsequent performance test on the same unit as specified by Minn. R.

7017.2025, subp. 3. The limit is final upon issuance of a permit amendment

incorporating the change.

Minn. R. 7017.2025, subp. 3

MONITORING REQUIREMENTS hdr

Monitoring Equipment Calibration: Annually calibrate all required monitoring

equipment (any requirements applying to continuous emission monitors are listed

separately in this permit).

Minn. R. 7007.0800, subp. 4(D)

Operation of Monitoring Equipment: Unless otherwise noted in Tables A, B, and/or

C, monitoring a process or control equipment connected to that process is not

necessary during periods when the process is shutdown, or during checks of the

monitoring systems, such as calibration checks and zero and span adjustments. If

monitoring records are required, they should reflect any such periods of process

shutdown or checks of the monitoring system.

Minn. R. 7007.0800, subp. 4(D)

RECORDKEEPING hdr

Recordkeeping: Retain all records at the stationary source for a period of five (5)

years from the date of monitoring, sample, measurement, or report. Records which

must be retained at this location include all calibration and maintenance records, all

original recordings for continuous monitoring instrumentation, and copies of all

reports required by the permit. Records must conform to the requirements listed in

Minn. R. 7007.0800, subp. 5(A).

Minn. R. 7007.0800, subp. 5(C)

Recordkeeping: Maintain records describing any insignificant modifications (as

required by Minn. R. 7007.1250, subp. 3) or changes contravening permit terms (as

required by Minn. R. 7007.1350, subp. 2), including records of the emissions

resulting from those changes.

Minn. R. 7007.0800, subp. 5(B)

When the Permittee determines that no permit amendment or notification is

required prior to making a change, the Permittee must retain records of all

calculations required under Minn. R. 7007.1200. For expiring permits, these

records shall be kept for a period of five years from the date the change was made

or until permit reissuance, whichever is longer. For nonexpiring permits, these

records shall be kept for a period of five years from the date that the change was

made. The records shall be kept at the stationary source for the current calendar

year of operation and may be kept at the stationary source or office of the

stationary source for all other years. The records may be maintained in either

electronic or paper format.

Minn. R. 7007.1200, subp. 4

REPORTING/SUBMITTALS hdr
TABLE A: LIMITS AND OTHER REQUIREMENTS 11/25/08

Minnesota Power - Laskin Energy Center

13700013 - 006

Facility Name:

Permit Number:

A-4

Shutdown Notifications: Notify the Commissioner at least 24 hours in advance of a

planned shutdown of any control equipment or process equipment if the shutdown

would cause any increase in the emissions of any regulated air pollutant. If the

owner or operator does not have advance knowledge of the shutdown, notification

shall be made to the Commissioner as soon as possible after the shutdown.

However, notification is not required in the circumstances outlined in Items A, B

and C of Minn. R. 7019.1000, subp. 3.

At the time of notification, the owner or operator shall inform the Commissioner of

the cause of the shutdown and the estimated duration. The owner or operator shall

notify the Commissioner when the shutdown is over.

Minn. R. 7019.1000, subp. 3

Breakdown Notifications: Notify the Commissioner within 24 hours of a breakdown

of more than one hour duration of any control equipment or process equipment if

the breakdown causes any increase in the emissions of any regulated air pollutant.

The 24-hour time period starts when the breakdown was discovered or reasonably

should have been discovered by the owner or operator. However, notification is not

required in the circumstances outlined in Items A, B and C of Minn. R. 7019.1000,

subp. 2.

At the time of notification or as soon as possible thereafter, the owner or operator

shall inform the Commissioner of the cause of the breakdown and the estimated

duration. The owner or operator shall notify the Commissioner when the

breakdown is over.

Minn. R. 7019.1000, subp. 2

Shutdown and Breakdown Reporting Requirement for the Dust Collector Systems

for Material Handling Equipment:

Shutdowns and breakdowns shall be reported on a quarterly basis to the Agency.

The quarterly report shall include an identification of any dust collector that

experienced a breakdown and/or shutdown, the time and reason for the breakdown

or shutdown, a description of any repairs made, and the date and time the dust

collector was placed back in service.

Minn. R. 7019.1000, subp. 2

Notification of Deviations Endangering Human Health or the Environment: As soon

as possible after discovery, notify the Commissioner or the state duty officer, either

orally or by facsimile, of any deviation from permit conditions which could endanger

human health or the environment.

Minn. R. 7019.1000, subp. 1

Notification of Deviations Endangering Human Health or the Environment Report:

Within 2 working days of discovery, notify the Commissioner in writing of any

deviation from permit conditions which could endanger human health or the

environment. Include the following information in this written description:

1. the cause of the deviation;

2. the exact dates of the period of the deviation, if the deviation has been corrected;

3. whether or not the deviation has been corrected;

4. the anticipated time by which the deviation is expected to be corrected, if not yet

corrected; and

5. steps taken or planned to reduce, eliminate, and prevent reoccurrence of the

deviation.

Minn. R. 7019.1000, subp. 1

Application for Permit Amendment: If a permit amendment is needed, submit an

application in accordance with the requirements of Minn. R. 7007.1150 through

Minn. R. 7007.1500. Submittal dates vary, depending on the type of amendment

needed.

Minn. R. 7007.1150 through Minn. R. 7007.1500

Extension Requests: The Permittee may apply for an Administrative Amendment to

extend a deadline in a permit by no more than 120 days, provided the proposed

deadline extension meets the requirements of Minn. R. 7007.1400, subp. 1(H).

Minn. R. 7007.1400, subp. 1(H)

Emission Inventory Report: due on or before April 1 of each calendar year following

permit issuance. The Permittee shall submit this on a form approved by the

Commissioner.

Minn. R. 7019.3000 through Minn. R. 7019.3100

Emission Fees: due 60 days after receipt of an MPCA bill. Minn. R. 7002.0005 through Minn. R. 7002.0095
TABLE A: LIMITS AND OTHER REQUIREMENTS 11/25/08

Minnesota Power - Laskin Energy Center

13700013 - 006

Facility Name:

Permit Number:

A-5

Subject Item: GP 001 Boilers

Associated Items: CE 004 Low Nox Burners

CE 005 Low Nox Burners

CE 006 Overfire Air

CE 007 Overfire Air

EU 001 Boiler - Unit #1; CE 001, CE 004, CE 006

EU 002 Boiler - Unit #2; CE 002, CE 005, CE 007

SV 001 Common Boiler Stack

What to do Why to do it

The Permittee shall meet either option 1 or option 2:

1.a. Individually validate EU 001 and EU 002 CO emissions are less than or equal

to the EU 001 and EU 002 CO 0.126 lb/mmBtu emission factor, and

1.b. Monitor, record, and report GP 001 emissions as required by 40 CFR Section

52.21(r)(6);

OR

2. Meet the GP 001 630 ton per year (12-month rolling sum basis) CO limit and all

associated monitoring, recordkeeping, and reporting requirements in table A of this

permit.

If either EU 001 or EU 002 CO emission factor testing results in a factor greater

than 0.126 lb/mmBtu, the Permittee shall follow option 2 and associated CO

monitoring and recordkeeping requirements in EU 001, EU 002, and GP 001 in

table A of this permit.

Title I Condition: 40 CFR Sections 52.21(b) &

52.21(r)(6) and Minn. R. 7007.3000

Reverting From Option 2 To Option 1: The Permittee may revert from option 2 to

option 1 under the following conditions:

1. a subsequent CO performance test on the same emission unit that previously

tested above 0.126 lb/mmBtu measures CO emissions no greater than 0.126

lb/mmBtu;

2. the Permittee continues to follow Section 52.21(r)(6) requirements during the

five-year period following the resumption of regular operation after completion of

modifications of both units, regardless if option 2 applies.

If both units previously tested above 0.126 lb/mmBtu, subsequent CO performance

tests must show CO emissions no greater than 0.126 lb/mmBtu for both units in

order to revert to option 1. This permit provision expires 5 years following

resumption of regular operations after completion of modifications of both units.

Title I Condition: 40 CFR Sections 52.21(b) &

52.21(r)(6) and Minn. R. 7007.3000

Carbon Monoxide: less than or equal to 630 tons/year using 12-month Rolling Sum

for both boilers combined. This limit applies at the end of the twelfth month after

initial startup of the first modified boiler, if the Permittee elects or is required to

meet this limit.

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000

Carbon Monoxide: If the Permittee elects to or is required to meet the GP 001 630

ton per year CO limit, the following cumulative limit as of month 'n' where n = 1, 2,

3, etc. applies after initial startup of the first modified boiler:

Month 1: 100 tons

Month 2: 200 tons

Month 3: 275 tons

Month 4: 350 tons

Month 5: 400 tons

Month 6: 450 tons

Month 7: 490 tons

Month 8: 520 tons

Month 9: 550 tons

Month 10: 580 tons

Month 11: 610 tons

Month 1 includes the month of initial startup of the first modified boiler. This

requirement terminates at the end of the twelfth month following initial startup of the

first modified boiler.

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000
TABLE A: LIMITS AND OTHER REQUIREMENTS 11/25/08

Minnesota Power - Laskin Energy Center

13700013 - 006

Facility Name:

Permit Number:

A-6

Carbon Monoxide: less than or equal to 738.0 tons/year on a calendar year basis

for both boilers combined. This limit and associated recordkeeping is suspended if

CO emission factor testing of EU 001 and EU 002 demonstrates a CO emission

factor less than or equal to 0.124 lb/mmBtu for each emission unit. This limit is

re-instated if a subsequent EU 001 or EU 002 CO emission factor test measures

CO in excess of 0.124 lb/mmBtu.

Minn. R. 7007.0800, subp. 2 to avoid 100 tpy

environmental review potential emission increase

threshold

GP 001 CO Emissions Monitoring and Recordkeeping: If the Permittee elects to or

is required to meet the 630.0 ton per year GP 001 CO limit, by the last day of each

month the Permittee shall calculate and record:

1. monthly GP 001 CO emissions for the previous calendar month by summing the

EU 001 CO and EU 002 CO emissions determined according to the requirements

listed under EU 001 and EU 002, respectively, from the previous calendar month;

2. GP 001 CO emissions from the previous twelve-month period by summing the

monthly GP 001 CO emissions from the previous twelve months.

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000

GP 001 CO Emissions Monitoring and Recordkeeping: The Permittee shall

calculate and record the GP 001 calendar year CO emissions by January 30 of

each year, for the previous calendar year.

Minn. R. 7007.0800, subp. 4 and 5 to avoid 100 tpy

environmental review potential emission increase

threshold

If either EU 001 or EU 002 CO emission factor testing results in a factor greater

than 0.126 lb/mmbtu, the Permittee may opt to perform additional analyses to

demonstrate that the CO emissions performance satisfies Prevention of Significant

Deterioration requirements under 40 CFR Section 52.21, and obtain a permit

according to 40 CFR Section 52.21.

40 CFR Section 52.21(a)(2)(iii)

Combustion Of Oily Cellulose-Based Sorbents (including rags): The Permittee is

permitted to burn oily cellulose-based sorbent and rags in both boilers. The

materials must be cellulose-based and are subject to the following limits:

1) 1.25 tons per hour; and

2) 25 tons per year (on a 12-month rolling sum basis).

The Permittee shall record the quantity of sorbent materials burned on an hourly

and 12-month rolling sum basis.

Title I Condition: to ensure that the emissions increase

from the addition of the fuel type is less than significant

as defined by 40 CFR Section 52.21 and Minn. R.

7007.3000
TABLE A: LIMITS AND OTHER REQUIREMENTS 11/25/08

Minnesota Power - Laskin Energy Center

13700013 - 006

Facility Name:

Permit Number:

A-7

Subject Item: GP 002 Scrubbers

What to do Why to do it

THE FOLLOWING REQUIREMENTS APPLY TO EACH SCRUBBER

INDIVIDUALLY

hdr

The Permittee shall operate and maintain the scrubbers (CE 001 and CE 002) at all

times that any emission unit controlled by the scrubbers (EU 001 and EU 002) is in

operation. The Permittee shall document periods of non-operation of the control

equipment.

Minn. R. 7007.0800, subps. 2 and 14

The Permittee shall operate and maintain control equipment such that it achieves

an overall control efficiency for Total Particulate Matter: greater than or equal to 90

percent

Minn. R. 7007.0800, subps. 2 and 14

The Permittee shall operate and maintain the scrubbers in accordance with the

Operation and Maintenance (O & M) Plan. The Permittee shall keep copies of the

O & M Plan available onsite for use by staff and MPCA staff.

40 CFR Section 64.7(b); Minn. R. 7017.0200

Temperature: less than or equal to 175 degrees F using 3-hour Average at the

common stack, unless a new limit is set pursuant to Minn. R. 7017.2025, subp. 3

based on the values recorded during the most recent MPCA-approved performance

test where compliance was demonstrated. The new limit shall be implemented

upon receipt of the Notice of Compliance letter granting preliminary approval. The

limit is final upon issuance of a permit amendment incorporating the change. If the

3-hour rolling average temperature is above the maximum temperature limit, the

PM emitted during that time shall be considered uncontrolled until the average

temperature is below the maximum temperature limit. This shall be reported as a

deviation.

Minn. R. 7007.0800, subps. 2 and 14

Temperature Monitoring: The Permittee shall maintain and operate a thermocouple

monitoring device that continuously indicates and records the stack temperature.

The monitoring equipment must be in use and properly maintained whenever

operation of the monitored control equipment is required. The monitoring device

shall have a margin of error less than +/- 2.0 percent of the temperature being

measured. The recording device shall also calculate the three-hour rolling average

temperature. Recorded values outside the range specified in this permit are

considered Deviations as defined by Minn. R. 7007.0100, subp. 8a.

Minn. R. 7007.0800, subps. 2 and 14; 40 CFR Section

64.3(b)(4)(ii); Minn. R. 7017.0200; 40 CFR Section

64.7(b); Minn. R. 7017.0200

Opacity: less than or equal to 20 percent using 3-hour average, unless a new limit

is set pursuant to Minn. R. 7017.2025, subp. 3 based on the values recorded during

the most recent MPCA-approved performance test where compliance was

demonstrated. The new limit shall be implemented upon receipt of the Notice of

Compliance letter granting preliminary approval. The limit is final upon issuance of

a permit amendment incorporating the change. If the 3-hour rolling average opacity

is above the maximum opacity limit, the PM emitted during that time shall be

considered uncontrolled until the average opacity is below the maximum opacity

limit. This shall be reported as a deviation.

Minn. R. 7007.0800, subps. 2 and 14; 40 CFR Section

64.3(b)(4)(ii); Minn. R. 7017.0200

Opacity Monitoring: The Permittee shall maintain and operate an opacity

monitoring device that continuously indicates and records the opacity of the stack.

The monitoring equipment must be in use and properly maintained whenever

operation of the monitored control equipment is required. The monitoring device

shall have a margin of error less than +/- 2.0 percent. The recording device shall

also calculate the three-hour rolling average. Recorded values outside the range

specified in this permit are considered Deviations as defined by Minn. R.

7007.0100, subp. 8a.

Minn. R. 7007.0800, subps. 2 and 14; 40 CFR Section

64.3(b)(4)(ii); Minn. R. 7017.0200; 40 CFR Section

64.7(b); Minn. R. 7017.0200

Daily Monitoring: The Permittee shall physically verify the operation of the

temperature recording device at least once each operating day to verify that it is

working and recording properly. The Permittee shall maintain a written or electronic

record of the daily verifications. The Permittee shall maintain a high temperature

alarm for the boiler operator.

Minn. R. 7007.0800, subps. 2 and 14; 40 CFR Section

64.3(b); Minn. R. 7017.0200

The Permittee shall maintain a continuous hard copy readout or computer disk file

of the temperature and opacity readings and calculated three hour rolling average

temperatures and opacity at the common stack.

Minn. R. 7007.0800, subps. 2 and 14; 40 CFR Section

64.9(b); Minn. R. 7017.0200

Annual Calibration: The Permittee shall calibrate the temperature monitor at least

annually and shall maintain a written record of the calibration and any action

resulting from the calibration.

40 CFR Section 64.3; Minn. R. 7017.0200

Quarterly Inspections: At least once per calendar quarter, the Permittee shall

inspect the control equipment internal and external system components. The

Permittee shall maintain a written record of the inspection and any corrective

actions taken resulting from the inspection.

40 CFR Section 64.3; Minn. R. 7017.0200

Annual Inspection: At least once per calendar year, the Permittee shall conduct an

internal inspection of the control device that includes all operating systems of the

control device. The Permittee shall maintain a written record of the inspection and

any action resulting from the inspection.

40 CFR Section 64.3; Minn. R. 7017.0200
TABLE A: LIMITS AND OTHER REQUIREMENTS 11/25/08

Minnesota Power - Laskin Energy Center

13700013 - 006

Facility Name:

Permit Number:

A-8

For periods when the scrubber exhaust is below the maximum temperature and

opacity, the Permittee shall use either one of the following when completing

calculations as required elsewhere in this permit:

a. The overall control efficiency limit specified in this permit for this equipment

(90%); or

b. The overall control efficiency determined during the most recent MPCA approved

performance test. If the tested efficiency is less than the efficiency limit in this

permit, the Permittee must use the tested value in all calculations until the

efficiency is demonstrated to be above the permit limit through a new test.

Minn. R. 7007.0800, subp. 4 and 5

Corrective Actions: If the temperature and/or opacity is above the maximum

specified by this permit or if the scrubber or any of its components are found during

the inspections to need repair, the Permittee shall take corrective action as soon as

possible. Corrective actions shall return the temperature and/or opacity to at least

the permitted maximum and/or include completion of necessary repairs identified

during the inspection, as applicable. Corrective actions include, but are not limited

to, those outlined in the O & M Plan for the scrubbers. The Permittee shall keep a

record of the type and date of any corrective action taken.

40 CFR Section 64.7(d); Minn. R. 7017.0200

Documentation of Need for Improved Monitoring: If the Permittee fails to achieve

compliance with an emission limitation or standard for which the monitoring did not

provide an indication of an excursion or exceedance while providing valid data, or

the results of compliance or performance testing document a need to modify the

existing maximum exhaust temperature, the Permittee shall promptly notify the

MPCA and, if necessary, submit a permit amendment application to address the

necessary monitoring changes.

40 CFR Section 64.7(e); Minn. R. 7017.0200

As required by 40 CFR Section 64.9(a)(2), for the Semi-Annual Deviations Report

listed in Table B of this permit and/or the Notification of Deviations Endangering

Human Health and the Environment listed earlier in Table A of this permit, as

applicable, the Permittee shall include the following related to the monitoring

identified as required by 40 CFR pt. 64: 1) Summary information on the number,

duration, and cause of excursions or exceedances, as applicable, and the

corrective action taken; and 2) Summary information on the number, duration, and

cause for monitor downtime incidents.

40 CFR Section 64.9(a)(2); Minn. R. 7017.0200

The Permittee shall maintain records of monitoring data, monitor performance data,

corrective actions taken, and other supporting information required to be

maintained. The Permittee may maintain records on alternative media, such as

microfilm, computer files, magnetic tape disks, or microfiche, provided that the use

of such alternative media allows for expeditious inspection and review, and does

not conflict with other applicable recordkeeping requirements.

40 CFR Section 64.9(b); Minn. R. 7017.0200
TABLE A: LIMITS AND OTHER REQUIREMENTS 11/25/08

Minnesota Power - Laskin Energy Center

13700013 - 006

Facility Name:

Permit Number:

A-9

Subject Item: SV 001 Common Boiler Stack

Associated Items: EU 001 Boiler - Unit #1; CE 001, CE 004, CE 006

EU 002 Boiler - Unit #2; CE 002, CE 005, CE 007

GP 001 Boilers

MR 002 

MR 005 

MR 006 Flow X-pattern

MR 007 Opacity

MR 008 SO2

MR 009 NOx

MR 010 CO2

What to do Why to do it

ADDITIONAL MR REQUIREMENTS LOCATED AT THE INDIVIDUAL MR LEVEL hdr

Sulfur Dioxide: less than or equal to 2.04 lbs/million Btu heat input using 1-Hour

Average .

Refer to EU 001 and EU 002 for the SO2 limit applicable to each emission unit.

Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R.

7007.0100, subps 7A, 7L & 7M; Minn. R. 7007.0800,

subps. 1, 2 & 4; Minn. R. 7009.0010-7009.0080

Nitrogen Oxides: less than or equal to 0.20 lbs/million Btu heat input using 365-day

Rolling Average

Minn. R. 7007.0800, subp. 2; this is a state-only

requirement not enforceable by the EPA administrator

or citizens under the Clean Air Act

COMS Monitoring Data: Owners or operators of all COMS shall reduce all data to

a one-minute averaging period. Opacity averages shall be calculated from all

equally spaced consecutive 10-second (or shorter) data points in the one-minute

averaging period.

Minn. R. 7017.1200, subps. 1, 2 and 3

COMS Calibration Error Audit: due before end of each calendar half-year following

COMS Certification Test. Conduct three point calibration error audits at least 3

months apart but no greater than 8 months apart. Conduct audits in accordance

with Minn. R. 7017.1210, subp. 3.

Minn. R. 7017.1210, subp. 3

COMS Continuous Operation: COMS must be operated and data recorded during

all periods of emission unit operation including periods of emission unit start-up,

shutdown, or malfunction except for periods of acceptable monitor downtime. This

requirement applies whether or not a numerical emission limit applies during these

periods. A COMS must not be bypassed except in emergencies where failure to

bypass would endanger human health, safety, or plant equipment.

Acceptable monitor downtime includes reasonable periods as listed in Items A, B,

C and D of Minn. R. 7017.1090, subp. 2.

Minn. R. 7017.1090, subp. 1

COMS Daily Calibration Drift Check: The Permittee must automatically, intrinsic to

the opacity monitor, check the zero and upscale (span) calibration drifts at least

once daily. The acceptable range is as defined in 40 CFR pt. 60, Appendix B, PS-1.

The COMS must be adjusted whenever the calibration drift (CD) exceeds twice the

specification of 40 CFR 60, Appendix B, PS-1.

Minn. R. 7017.1210, subp. 2

Recordkeeping: The owner or operator must retain records of all COMS/CEMS

monitoring data and support information for a period of five years from the date of

the monitoring sample, measurement, or report. Records shall be kept at the

source.

Minn. R. 7017.1130

CEMS QA/QC The owner or operator of an affected facility shall operate, calibrate,

and maintain each CEMS according to the QA/QC procedures in 40 CFR pt. 75,

Appendix B as amended.

40 CFR Section 75.21

Daily Calibration Error (CE) Test: conduct daily CE testing on all CEMS required by

the Acid Rain Program, in accordance with 40 CFR pt. 75 App B.

40 CFR pt. 75 App B, section 2.1

CEMS Relative Accuracy Test Audit (RATA): due before the end of each calendar

half year following CEM Certification Test (or due each year, depending on the

results of the previous test). Conduct a RATA on all CEMS required by the Acid

Rain Program, in accordance with 40 CFR pt. 75 App B. If the RATA results

indicate a relative accuracy of 7.5% or less, the next RATA is not required for

another year.

40 CFR pt. 75 App B, section 2.3
TABLE A: LIMITS AND OTHER REQUIREMENTS 11/25/08

Minnesota Power - Laskin Energy Center

13700013 - 006

Facility Name:

Permit Number:

A-10

Linearity and Leak Check Test (Acid Rain Program): due before end of each

calendar quarter following CEM Certification Test. Conduct a quarterly linearity test

on all CEMS required by the Acid Rain Program, in accordance with 40 CFR pt. 75

App B.

40 CFR pt. 75 App B, section 2.2

Relative Accuracy Test Audit (RATA) Notification: due 30 days before CEMS

Relative Accuracy Test Audit (RATA).

Minn. R. 7017.1180, subp. 2
TABLE A: LIMITS AND OTHER REQUIREMENTS 11/25/08

Minnesota Power - Laskin Energy Center

13700013 - 006

Facility Name:

Permit Number:

A-11

Subject Item: EU 001 Boiler - Unit #1; CE 001, CE 004, CE 006

Associated Items: CE 004 Low Nox Burners

CE 006 Overfire Air

GP 001 Boilers

SV 001 Common Boiler Stack

What to do Why to do it

LIMITS AND OPERATING REQUIREMENTS hdr

Total Particulate Matter: less than or equal to 0.60 lbs/million Btu heat input Minn. R. 7011.0510, subp. 1

Opacity: less than or equal to 20 percent opacity using 6-minute Average except for

one six-minute period per hour of not more than 60 percent opacity.

Minn. R. 7011.0510, subp. 2

Sulfur Dioxide: less than or equal to 4.0 lbs/million Btu heat input using 1-Hour

Average period for solid fuels, and 2.0 lb/mmBtu when burning liquid fuels. When

fossil fuels are burned simultaneously in any combination, the applicable standard

shall be determined by proration using the following formula: w=[2y+4z]/(y+z)

where y is the % heat input from liquid fossil fuel and z is the % heat input from

solid fossil fuels.

Refer to SV 001 for additional SO2 limit applicable to the common stack.

Minn. R. 7011.0510, subp. 1

Nitrogen Oxides: less than or equal to 0.20 lbs/million Btu heat input using 365-day

Rolling Average

Minn. R. 7007.0800, subp. 2; this is a state-only

requirement not enforceable by the EPA administrator

or citizens under the Clean Air Act

Carbon Monoxide: less than or equal to 0.126 lbs/million Btu heat input (this is an

emission factor and not a limit). The Permittee shall validate this factor through

performance testing. If performance testing shows a factor greater than 0.126

lb/mmBtu, the Permittee shall meet the GP 001 630.0 tpy limit.

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000

Fuel use: limited to sub-bituminous and bituminous coal, distillate oil, natural gas,

boiler cleaning agents, non-hazardous petroleum distillate solvents and derived

fuels, used oil, oily coal (coal with oil spilled on it), and oily cellulose-based

sorbents (including rags).

Minn. Stat. Section 116.07, subd. 4a;

Minn. R. 7007.0800, subp. 2

Boiler cleaning agents limited to: EDTA type and Ammonium Bromate, are

generated on-site, 5% of total fuel mass, oxygen limited to 3% or greater, agents

may only be burned while the boiler is operating at 75 percent of rated capacity or

greater.

Minn. Stat. Section 116.07, subd. 4a;

Minn. R. 7007.0800, subp. 2

Fuel Usage: less than or equal to 720 gallons/hour and less than 2,500,000 gallons

annually of off-specification and on-specification used oil. Used oil shall be burned

in accordance with Minn. R. ch. 7045.

Minn. Stat. Section 116.07, subd. 4a;

Minn. R. 7007.0800, subp. 2

EU 001 Bituminous Coal Operations: If the Permittee combusts any bituminous

coal, the Permittee shall conduct a CO performance test while burning bituminous

coal. The Permittee may continue burning bituminous coal in EU 001 after

completion of testing.

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000

EU 001 CO Emissions Indicator: The Permittee shall operate EU 001 so that CO

(ppm) measured by the emissions indicator does not exceed a value based on

values measured during the most recent MPCA-approved performance stack test

for evaluating the EU 001 CO emission factor. The current CO emission indicator is

100 ppm on a 30-day rolling average based on July 2007 test data.

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000

ACID RAIN PROGRAM REQUIREMENTS hdr

Comply with the applicable Acid Rain emissions limitation for sulfur dioxide. Takes

effect for years beginning January 1, 2000.

40 CFR Section 72.9(c)(1)(ii), 40 CFR Section

72.9(g)(4)

Application for NOx limits: Submit a complete permit application and compliance

plan for NOx emissions in accordance with 40 CFR Section 76.9.

40 CFR Section 76.9(b)(2)
TABLE A: LIMITS AND OTHER REQUIREMENTS 11/25/08

Minnesota Power - Laskin Energy Center

13700013 - 006

Facility Name:

Permit Number:

A-12

NOx Averaging Plan

Beginning January 1, 2000 either:

Maintain an annual average NOx emission rate of 0.40 lbs/mmBtu and limit the

annual heat input to less than or equal to 4,600,000 mmBtu per year.

 OR

Maintain a Btu-weighted annual average emission rate in lbs/mmBtu, averaged

over the units specified in the NOx averaging plan, that is less than or equal to the

Btu-weighted annual average emission rate averaged over the same units had they

each been operated during the same period of time in compliance with the

applicable emission limitations in 40 CFR Sections 76.5, 76.6, or 76.7. Units

covered in the plan are:

Plant Boiler ID#

Clay Boswell 1, 2, 3, 4

Syl Laskin 1, 2

Taconite Harbor 1, 2, 3

40 CFR Section 76.11

Recordkeeping: Keep on site at the source each of the following documents for a

period of 5 years from the date the document is created: The certificate of

representation, all emissions monitoring information, copies of all reports,

compliance certifications, and other submissions or records made under the Acid

Rain Program, copies of all documents used to complete an acid rain permit

application.

40 CFR Section 72.9(f)(l)

Apply for Acid Rain Program Permit reissuance: The designated representative

shall submit a complete Acid Rain permit application for each source with an

affected unit at least 6 months prior to the expiration of an existing Acid Rain Permit

in accordance with 40 CFR Section 72.30(c).

40 CFR Section 72.30(c)

Certify Acid Rain Program Submittals. Each submission under the Acid Rain

Program shall be submitted, signed, and certified by the designated representative

or the alternate designated representative for all sources on behalf of which the

submission is made in accordance with 40 CFR Section 72.21.

40 CFR Section 72.21

Hold allowances as of the allowance transfer deadline, in the unit's compliance

subaccount not less than the total annual emissions of sulfur dioxide for the

previous calendar year. Takes effect for years beginning January 1, 2000.

Allowances shall be held in, deducted from, or transferred among Allowance

Tracking System accounts in accordance with the Acid Rain Program.

40 CFR Section 72.9(c)(1)(i), 40 CFR Section

72.9(g)(4)

The owner or operator shall measure opacity, and all SO2, NOx, and CO2

emissions for each affected unit in accordance with 40 CFR Section 75.10.

40 CFR Section 75.10

PERFORMANCE TESTING hdr

Performance Test: due before end of each calendar 60 months starting 07/25/2007

to evaluate compliance with the CO emission factor to avoid major modification

under 40 CFR Section 52.21(b) and Minn. R. 7007.3000. The tests shall be

conducted at an interval not to exceed 60 months between test dates. The test

shall be conducted while combusting coal as a single fuel, a combination of coal

and fuel oil, and a combination of coal and natural gas.

A one-time 60-day extension was granted in 2007.

Minn. R. 7017.2020, subp.1

Performance Test: due before end of each 60 months starting 06/03/1997 to

determine compliance with the particulate matter emissions limit in Minn. R.

7011.0510 subp 1. The tests shall be conducted at an interval not to exceed 60

months between test dates.

A one-time 120-day extension was granted in 2007.

Minn. R. 7017.2020, subp. 1

Boiler Alternative Operating Conditions for Performance Testing:

Alternative Operating Conditions during testing are defined as 90% to 100% of the

boiler's maximum normal (continuous) operating load or the maximum permitted

operating rate, whichever is lower. The basis for this number must be included in

the test plan. If testing is conducted at the alternative operating condition

established, an operating limit will not be established as a result of performance

testing.

In no case will the new operating rate limit be higher than allowed by an existing

permit condition.

Minn. R. 7017.2025, subp. 2.A. and 3.B.
TABLE A: LIMITS AND OTHER REQUIREMENTS 11/25/08

Minnesota Power - Laskin Energy Center

13700013 - 006

Facility Name:

Permit Number:

A-13

Boiler Operating Conditions Not Meeting the Alternative Operating Conditions

During Performance Testing:

If performance testing is not conducted at or above the established alternative

operating condition, then the boiler operating rate will be limited on an 8-hour block

average based on the following:

(1) If the results of the performance test are greater than 80% of any applicable

emission limit for which compliance is demonstrated, then boiler operation will be

limited to the tested operating rate.

(2) If results are less than or equal to 80% of all applicable emission limits for which

compliance is demonstrated, boiler operation will be limited to the tested operating

rate.

In no case will the new operating rate limit be higher than allowed by an existing

permit condition.

Minn. R. 7017.2025, subp. 3.B.

STET (Short Term Emergency and Testing) Operating hours limit:

The boiler may operate up to 40 hours per year to demonstrate the Uniform Rating

of Generating Equipment (URGE) capacity and to meet emergency energy supply

needs. Maintain documentation of all STET operation to demonstrate compliance

with this limit. The boiler must meet emission limits during STET operation.

Minn. R. 7007.0800, subp. 2

STET Operation Definition that applies to Boilers that Meet or do Not Meet the

Alternative Operating Condition for Performance Testing:

If performance test results demonstrate compliance at 80% or less of any

applicable emission limits for any tested pollutant, STET operation is defined as

operation beyond 110% of the average operating rate achieved during that

performance test.

If performance test results demonstrate compliance at greater than 80% of any

applicable emission limit for any tested pollutant, STET operation is defined as

operation beyond 100% of the average operating rate achieved during that

performance test.

In no case will STET operation be higher than allowed by an existing permit

condition.

Minn. R. 7007.0800, subp. 2

The results of a performance test are not final until issuance of a review letter by

MPCA, unless specified otherwise by Minn. R. 7017.2001 - 7017.2060.

Minn. R. 7017.2020, subp. 4

MONITORING AND RECORDKEEPING hdr

Recordkeeping: maintain records of the occurrence and duration of any startup,

shutdown, or malfunction in the operation of the facility including malfunction of the

air pollution control equipment or any periods during which a continuous monitoring

system or monitoring device is inoperative.

Minn. R. 7007.0800, supb. 2

Excess emissions and monitoring system performance reports shall include the

information required in 40 CFR Section 60.7(c) and (d). MPCA supplied forms

DRF-1 and DRF-2 may be used to meet this requirement.

Minn. R. 7007.0800, subp. 2

EU 001 CO Emissions Indicator Monitoring and Recordkeeping: Calculate the

arithmetic average of all hourly emission rates for CO for 30 calendar days. The

30-day rolling hourly average is calculated once each calendar day by summing the

hourly CO emission concentrations measured during the previous 30 calendar

days, and dividing by the number of hourly data values. Downtime of greater than

one hour duration shall not be included in the 30-day rolling average.

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000

EU 001 CO Emissions Indicator Monitoring and Recordkeeping: The Permittee

shall install, operate, and maintain a process CO monitor (ppm monitor primarily for

the boiler operator) upstream of the EU 001 air heater, and record the indicator

measurements. The monitoring and recordkeeping equipment shall be operated

and maintained at all times during EU 001 operation.

CO concentration will not exceed a value based on values recorded during the

most recent MPCA-approved performance test. The measurement frequency and

averaging period associated with this emissions indicator will be derived by the

Permittee through analysis of the correlation between indicator readings and the

first performance test results.

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000
TABLE A: LIMITS AND OTHER REQUIREMENTS 11/25/08

Minnesota Power - Laskin Energy Center

13700013 - 006

Facility Name:

Permit Number:

A-14

EU 001 CO Emissions Monitoring and Recordkeeping: If the Permittee elects or is

required to meet the 630 tpy (on a 12-month rolling sum basis) limit in GP 001, by

the last day of each month commencing with the month of initial startup of the first

boiler after LNB and OFA modifications are completed, the Permittee shall:

1. calculate and record EU 001 monthly fuel usage of bituminous and

sub-bituminous coal;

2. calculate and record monthly EU 001 CO emissions using the following equation:

EU 001 CO = (FU * HC * EF)/2000

where:

EU 001 CO = monthly EU 001 CO emissions for each coal type (tons)

FU = EU 001 monthly fuel consumption for each coal type (tons)

HC = fuel heat content for each coal type (mmBtu/ton)

EF = current EU 001 CO emission factor for each coal type (lb/mmBtu)

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000

EU 001 Bituminous Coal CO Monitoring: If the Permittee combusts bituminous

coal, the Permittee shall calculate bituminous coal CO emissions using the EU 001

subbituminous coal CO emission factor until receipt of written MPCA confirmation

of the EU 001 bituminous coal CO test results.

After receipt of written MPCA confirmation of the EU 001 bituminous coal CO test

results, the Permittee shall determine EU 001 bituminous coal CO emissions using

the approved EU 001 bituminous coal emission factor. The Permittee shall also

recalculate EU 001 bituminous coal CO emissions that were initially determined

using the subbituminous coal CO emission factor, using the approved EU 001

bituminous coal emission factor.

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000
TABLE A: LIMITS AND OTHER REQUIREMENTS 11/25/08

Minnesota Power - Laskin Energy Center

13700013 - 006

Facility Name:

Permit Number:

A-15

Subject Item: EU 002 Boiler - Unit #2; CE 002, CE 005, CE 007

Associated Items: CE 005 Low Nox Burners

CE 007 Overfire Air

GP 001 Boilers

SV 001 Common Boiler Stack

What to do Why to do it

LIMITS AND OPERATING REQUIREMENTS hdr

Total Particulate Matter: less than or equal to 0.60 lbs/million Btu heat input Minn. R. 7011.0510, subp. 1

Opacity: less than or equal to 20 percent opacity using 6-minute Average except for

one six-minute period per hour of not more than 60 percent opacity.

Minn. R. 7011.0510, subp. 2

Sulfur Dioxide: less than or equal to 4.0 lbs/million Btu heat input using 1-Hour

Average period for solid fuels, and 2.0 lb/mmBtu when burning liquid fuels. When

fossil fuels are burned simultaneously in any combination, the applicable standard

shall be determined by proration using the following formula: w=[2y+4z]/(y+z)

where y is the % heat input from liquid fossil fuel and z is the % heat input from

solid fossil fuels.

Refer to SV 001 for additional SO2 limit applicable to the common stack.

Minn. R. 7011.0510, subp. 1

Nitrogen Oxides: less than or equal to 0.20 lbs/million Btu heat input using 365-day

Rolling Average

Minn. R. 7007.0800, subp. 2; this is a state-only

requirement not enforceable by the EPA administrator

or citizens under the Clean Air Act

Carbon Monoxide: less than or equal to 0.126 lbs/million Btu heat input (this is an

emission factor and not a limit). The Permittee shall validate this factor through

performance testing. If performance testing shows a factor greater than 0.126

lb/mmBtu, the Permittee shall meet the GP 001 630 tpy limit.

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000

Fuel use: limited to sub-bituminous and bituminous coal, distillate oil, natural gas,

boiler cleaning agents, non-hazardous petroleum distillate solvents and derived

fuels, used oil, oily coal (coal with oil spilled on it), and oily cellulose-based

sorbents (including rags).

Minn. Stat. Section 116.07, subd. 4a;

Minn. R. 7007.0800, subp. 2

Boiler cleaning agents limited to: EDTA type and Ammonium Bromate, are

generated on-site, 5% of total fuel mass, oxygen limited to 3% or greater, agents

may only be burned while the boiler is operating at 75 percent of rated capacity or

greater.

Minn. Stat. Section 116.07, subd. 4a;

Minn. R. 7007.0800, subp. 2

Fuel Usage: less than or equal to 720 gallons/hour and less than 2,500,000 gallons

annually of off-specification and on-specification used oil. Used oil shall be burned

in accordance with Minn. R. ch. 7045.

Minn. Stat. Section 116.07, subd. 4a;

Minn. R. 7007.0800, subp. 2

EU 002 Bituminous Coal Operations: If the Permittee combusts any bituminous

coal, the Permittee shall conduct a CO performance test while burning bituminous

coal. The Permittee may continue burning bituminous coal in EU 002 after

completion of testing.

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000

EU 002 CO Emissions Indicator: The Permittee shall operate EU 002 so that CO

(ppm) measured by the emissions indicator does not exceed a value based on

values measured during the most recent MPCA-approved performance stack test

for evaluating the EU 002 CO emission factor. The current CO emission indicator

is 100 ppm on a 30-day rolling average based on July 2007 test data.

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000

ACID RAIN PROGRAM REQUIREMENTS hdr

Comply with the applicable Acid Rain emissions limitation for sulfur dioxide. Takes

effect for years beginning January 1, 2000.

40 CFR Section 72.9(c)(1)(ii), 40 CFR Section

72.9(g)(4)

Application for NOx limits: Submit a complete permit application and compliance

plan for NOx emissions in accordance with 40 CFR Section 76.9.

40 CFR Section 76.9(b)(2)
TABLE A: LIMITS AND OTHER REQUIREMENTS 11/25/08

Minnesota Power - Laskin Energy Center

13700013 - 006

Facility Name:

Permit Number:

A-16

NOx Averaging Plan

Beginning January 1, 2000 either:

Maintain an annual average NOx emission rate of 0.40 lbs/MMBtu and limit the

annual heat input to less than or equal to 4,600,000 MMBtu per year.

 OR

Maintain a Btu-weighted annual average emission rate in lbs/MMBtu, averaged

over the units specified in the NOx averaging plan, that is less than or equal to the

Btu-weighted annual average emission rate averaged over the same units had they

each been operated during the same period of time in compliance with the

applicable emission limitations in 40 CFR Sections 76.5, 76.6, or 76.7. Units

covered in the plan are:

Plant Boiler ID#

Clay Boswell 1, 2, 3, 4

Syl Laskin 1, 2

Taconite Harbor 1, 2, 3

40 CFR Section 76.11

Recordkeeping: Keep on site at the source each of the following documents for a

period of 5 years from the date the document is created: The certificate of

representation, all emissions monitoring information, copies of all reports,

compliance certifications, and other submissions or records made under the Acid

Rain Program, copies of all documents used to complete an acid rain permit

application.

40 CFR Section 72.9(f)(l)

Apply for Acid Rain Program Permit reissuance: The designated representative

shall submit a complete Acid Rain permit application for each source with an

affected unit at least 6 months prior to the expiration of an existing Acid Rain Permit

in accordance with 40 CFR Section 72.30(c).

40 CFR Section 72.30(c)

Certify Acid Rain Program Submittals. Each submission under the Acid Rain

Program shall be submitted, signed, and certified by the designated representative

or the alternate designated representative for all sources on behalf of which the

submission is made in accordance with 40 CFR Section 72.21.

40 CFR Section 72.21

Hold allowances as of the allowance transfer deadline, in the unit's compliance

subaccount not less than the total annual emissions of sulfur dioxide for the

previous calendar year. Takes effect for years beginning January 1, 2000.

Allowances shall be held in, deducted from, or transferred among Allowance

Tracking System accounts in accordance with the Acid Rain Program.

40 CFR Section 72.9(c)(1)(i), 40 CFR Section

72.9(g)(4)

The owner or operator shall measure opacity, and all SO2, NOx, and CO2

emissions for each affected unit in accordance with 40 CFR Section 75.10.

40 CFR Section 75.10

PERFORMANCE TESTING hdr

Performance Test: due before end of each 60 months starting 06/03/1997 to

determine compliance with the particulate matter emissions limit in Minn. R.

7011.0510 subp. 1. The tests shall be conducted at an interval not to exceed 60

months between test dates.

A one-time 120-day extension was granted in 2007.

Minn. R. 7017.2020, subp. 1

Performance Test: due before end of each calendar 36 months starting 07/25/2007

to evaluate compliance with the CO emission factor to avoid major modification

under 40 CFR Section 52.21(b) and Minn. R. 7007.3000. The tests shall be

conducted at an interval not to exceed 36 months between test dates while

combusting coal as a single fuel or a combination of coal and fuel oil.

Minn. R. 7017.2020, subp. 1

Performance Test: due before end of each calendar 60 months starting 07/25/2007

to determine compliance with the CO emission factor to avoid major modification

under 40 CFR Section 52.21(b) and Minn. R. 7007.3000. The tests shall be

conducted at an interval not to exceed 60 months between test dates while

combusting a combination of natural gas and coal.

Minn. R. 7017.2020, subp.1

Boiler Alternative Operating Conditions for Performance Testing:

Alternative Operating Conditions during testing are defined as 90% to 100% of the

boiler's maximum normal (continuous) operating load or the maximum permitted

operating rate, whichever is lower. The basis for this number must be included in

the test plan. If testing is conducted at the alternative operating condition

established, an operating limit will not be established as a result of performance

testing.

In no case will the new operating rate limit be higher than allowed by an existing

permit condition.

Minn. R. 7017.2025, subp. 2.A. and 3.B.
TABLE A: LIMITS AND OTHER REQUIREMENTS 11/25/08

Minnesota Power - Laskin Energy Center

13700013 - 006

Facility Name:

Permit Number:

A-17

Boiler Operating Conditions Not Meeting the Alternative Operating Conditions

During Performance Testing:

If performance testing is not conducted at or above the established alternative

operating condition, then the boiler operating rate will be limited on an 8-hour block

average based on the following:

(1) If the results of the performance test are greater than 80% of any applicable

emission limit for which compliance is demonstrated, then boiler operation will be

limited to the tested operating rate.

(2) If results are less than or equal to 80% of all applicable emission limits for which

compliance is demonstrated, boiler operation will be limited to the tested operating

rate.

In no case will the new operating rate limit be higher than allowed by an existing

permit condition.

Minn. R. 7017.2025, subp. 3.B.

STET (Short Term Emergency and Testing) Operating hours limit:

The boiler may operate up to 40 hours per year to demonstrate the Uniform Rating

of Generating Equipment (URGE) capacity and to meet emergency energy supply

needs. Maintain documentation of all STET operation to demonstrate compliance

with this limit. The boiler must meet emission limits during STET operation.

Minn. R. 7007.0800, subp. 2

STET Operation Definition that applies to Boilers that Meet or do Not Meet the

Alternative Operating Condition for Performance Testing:

If performance test results demonstrate compliance at 80% or less of any

applicable emission limits for any tested pollutant, STET operation is defined as

operation beyond 110% of the average operating rate achieved during that

performance test.

If performance test results demonstrate compliance at greater than 80% of any

applicable emission limit for any tested pollutant, STET operation is defined as

operation beyond 100% of the average operating rate achieved during that

performance test.

In no case will STET operation be higher than allowed by an existing permit

condition.

Minn. R. 7007.0800, subp. 2

The results of a performance test are not final until issuance of a review letter by

MPCA, unless specified otherwise by Minn. R. 7017.2001 - 7017.2060.

Minn. R. 7017.2020, subp. 4

MONITORING AND RECORDKEEPING hdr

Recordkeeping: maintain records of the occurrence and duration of any startup,

shutdown, or malfunction in the operation of the facility including malfunction of the

air pollution control equipment or any periods during which a continuous monitoring

system or monitoring device is inoperative.

Minn. R. 7007.0800, subp. 2

Excess emissions and monitoring system performance reports shall include the

information required in 40 CFR Sections 60.7(c) and (d). MPCA supplied forms

DRF-1 and DRF-2 may be used to meet this requirement.

Minn. R. 7007.0800, subp. 2

EU 002 CO Emissions Indicator Monitoring and Recordkeeping: Calculate the

arithmetic average of all hourly emission rates for CO for 30 calendar days. The

30-day rolling hourly average is calculated once each calendar day by summing the

hourly CO emission concentrations measured during the previous 30 calendar

days, and dividing by the number of hourly data values. Downtime of greater than

one hour duration shall not be included in the 30-day rolling average.

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000

EU 002 CO Emissions Indicator Monitoring and Recordkeeping: The Permittee

shall install, operate, and maintain a process CO monitor (ppm monitor primarily for

the boiler operator) upstream of the EU 002 air heater, and record the indicator

measurements. The monitoring and recordkeeping equipment shall be operated

and maintained at all times during EU 002 operation.

CO concentration will not exceed a value based on values recorded during the

most recent MPCA-approved performance test. The measurement frequency and

averaging period associated with this emissions indicator will be derived by the

Permittee through analysis of the correlation between indicator readings and the

first performance test results.

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000
TABLE A: LIMITS AND OTHER REQUIREMENTS 11/25/08

Minnesota Power - Laskin Energy Center

13700013 - 006

Facility Name:

Permit Number:

A-18

EU 002 CO Emissions Monitoring and Recordkeeping: If the Permittee elects or is

required to meet the 630 tpy (on a 12-month rolling sum basis) limit in GP 001, by

the last day of each month commencing with the month of initial startup of the first

boiler after LNB and OFA modifications are completed, the Permittee shall:

1. calculate and record EU 002 monthly fuel usage of bituminous and

sub-bituminous coal;

2. calculate and record monthly EU 002 CO emissions using the following equation:

EU 002 CO = (FU * HC * EF)/2000

where:

EU 002 CO = monthly EU 002 CO emissions for each coal type (tons)

FU = EU 002 monthly fuel consumption for each coal type (tons)

HC = fuel heat content for each coal type (mmBtu/ton)

EF = current EU 002 CO emission factor for each coal type (lb/mmBtu)

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000

EU 002 Bituminous Coal CO Monitoring: If the Permittee combusts bituminous

coal, the Permittee shall calculate bituminous coal CO emissions using the EU 002

subbituminous coal CO emission factor until receipt of written MPCA confirmation

of the EU 002 bituminous coal CO test results.

After receipt of written MPCA confirmation of the EU 002 bituminous coal CO test

results, the Permittee shall determine EU 002 bituminous coal CO emissions using

the approved EU 002 bituminous coal emission factor. The Permittee shall also

recalculate EU 002 bituminous coal CO emissions that were initially determined

using the subbituminous coal CO emission factor, using the approved EU 002

bituminous coal emission factor.

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000
TABLE A: LIMITS AND OTHER REQUIREMENTS 11/25/08

Minnesota Power - Laskin Energy Center

13700013 - 006

Facility Name:

Permit Number:

A-19

Subject Item: EU 003 Coal Crusher

Associated Items: CE 003 6% or Greater Moisture Content

SV 002 Coal Crusher

What to do Why to do it

Total Particulate Matter: less than or equal to 0.3 grains/dry standard cubic foot of

exhaust gas unless required to further reduce emissions to meet the less stringent

limit of either Minn. R. 7011.0730 or Minn. R. 7011.0735.

Minn. R. 7011.0715, subp. 1(A)

Opacity: less than or equal to 20 percent opacity Minn. R. 7011.0715, subp. 1(B)

TABLE B: SUBMITTALS

Facility Name: Minnesota Power - Laskin Energy Center

Permit Number: 13700013 - 006

B-1 11/25/08

Also, where required by an applicable rule or permit condition, send to the Permit Technical Advisor notices of:

- accumulated insignificant activities,

- installation of control equipment,

- replacement of an emissions unit, and

- changes that contravene a permit term.

Send submittals that are required to be submitted to the U.S. EPA regional office to:

 Mr. George Czerniak

 Air and Radiation Branch

 EPA Region V

 77 West Jackson Boulevard

 Chicago, Illinois 60604

Table B lists most of the submittals required by this permit. Please note that some submittal requirements may appear in Table A

or, if applicable, within a compliance schedule located in Table C. Table B is divided into two sections in order to separately list

one-time only and recurrent submittal requirements.

Send submittals that are required by the Acid Rain Program to:

 U.S. Environmental Protection Agency

 Clean Air Markets Division

 1200 Pennsylvania Avenue NW (6204N)

 Washington, D.C. 20460

Send any application for a permit or permit amendment to:

 AQ Permit Technical Advisor

 Industrial Division

 Minnesota Pollution Control Agency

 520 Lafayette Road North

 St. Paul, Minnesota 55155-4194

Each submittal must be postmarked or received by the date specified in the applicable Table. Those submittals required by parts

7007.0100 to 7007.1850 must be certified by a responsible official, defined in Minn. R. 7007.0100, subp. 21. Other submittals shall

be certified as appropriate if certification is required by an applicable rule or permit condition.

Unless another person is identified in the applicable Table, send all other submittals to:

 AQ Compliance Tracking Coordinator

 Industrial Division

 Minnesota Pollution Control Agency

 520 Lafayette Road North

 St. Paul, Minnesota 55155-4194
TABLE B: ONE TIME SUBMITTALS OR NOTIFICATIONS

Facility Name: Minnesota Power - Laskin Energy Center

Permit Number: 13700013 - 006

B-2 11/25/08

What to send When to send Portion of Facility Affected

Application for Permit Reissuance due 180 days before expiration of Existing

Permit

Total Facility
TABLE B: RECURRENT SUBMITTALS

Facility Name: Minnesota Power - Laskin Energy Center

Permit Number: 13700013 - 006

B-3 11/25/08

What to send When to send Portion of Facility Affected

COMS Calibration Error Audit Results

Summary

 due 30 days after end of each calendar

quarter following Permit Issuance if

performed.

MR007

Excess Emissions/Downtime Reports (EER's) due 30 days after end of each calendar

quarter starting 05/12/1997 (Submit

Deviations Reporting Form DRF-1 as

amended). The EER shall indicate all periods

of exceedances of the limit including

exceedances allowed by an applicable

standard, i.e. during startup, shutdown, and

malfunctions.

SV001

Linearity Test Results Summary due 30 days after end of each calendar

quarter starting 06/26/1997 if Linearity and

Leak Check is performed.

MR009, MR010

Linearity Test Results Summary due 30 days after end of each calendar

quarter starting 06/26/1997 if Linearity and

Leak Check Test is performed.

MR008

Relative Accuracy Test Audit (RATA) Results

Summary

 due 30 days after end of each calendar

quarter starting 06/26/1997 if RATA is

performed.

MR008, MR009, MR010

Semiannual Deviations Report due 30 days after end of each calendar

half-year following Permit Issuance. The first

semiannual report submitted by the Permittee

shall cover the calendar half-year in which the

permit is issued. The first report of each

calendar year covers January 1 - June 30.

The second report of each calendar year

covers July 1 - December 31. If no deviations

have occurred, the Permittee shall submit the

report stating no deviations.

Total Facility

Compliance Certification Report (Acid Rain

Program)

 due 60 days after end of each calendar year

starting 01/01/2000 an annual compliance

certification report for the unit in accordance

with 40 CFR Section 72.90(a). The report

shall include all information required by 40

CFR Sections 72.90(b) and (c).

EU001, EU002

Compliance Certification due 30 days after end of each calendar year

following Permit Issuance (for the previous

calendar year). The Permittee shall submit

this on a form approved by the Commissioner,

both to the Commissioner and to the US EPA

regional office in Chicago. This report covers

all deviations experienced during the calendar

year.

Total Facility

APPENDIX B - Acid Rain Permit Application 

Facility Name: Minnesota Power - Laskin Energy Center 

Permit Number: 13700013-006 

2007 NOx 

Compliance and Avera

APPENDIX C - Insignificant Activities Required to be Listed 

Facility Name: Minnesota Power – Laskin Energy Center 

Permit Number: 13700013-006 

Insignificant Activities and Applicable Requirements

Minn. R. 

Rule Description of the Activity Applicable Requirement 

Minn. R. 

7007.1300, 

subp. 4(B) 

Emissions units with emissions less than all the following limits 

but not included in subpart 2 must be listed in a part 70 permit 

application: 

potential emissions of 2.28 pounds per hour or actual 

emissions of one ton per year for particulate matter, particulate 

matter less than ten microns, nitrogen oxide, sulfur dioxide, and 

VOCs. 

The facility performs the following operations that emit 

less than 1 ton per year of listed pollutants. 

 Railcar unloading 

 Coal conveying to crusher house 

 Coal conveying to tripper 

 Coal conveying from tripper to bunkers 

 Coal conveying drop-off fugitives 

 Ash storage wind erosion 

 Fuel oil handling fugitives from pumps and piping. 

Minn. R. 7011.0710/0715 

Minn. R. 

7007.1300, 

subp. 3(H)(3) 

Miscellaneous: brazing, soldering or welding equipment; 

Facility performs some welding activities.

Minn. R. 7011.0710/0715 

Minn. R. 

7007.1300, 

subp. 3(J) 

Fugitive Emissions from roads and parking lots. 

Facility has unpaved roads. 

Minn. R. 7011.0150 

Minn. R. 

7008.4110 

Conditionally insignificant PM And PM10 emitting operations 

Facility has a lime bin vent for lime storage and delivery 

with controls that meet the requirements for conditionally 

insignificant. 

Minn. R. 7011.0710/0715 

APPENDIX D - Compliance Assurance Monitoring Plan 

Facility Name: Minnesota Power – Laskin Energy Center 

Permit Number: 13700013-006 

Laskin Energy Center 

CAM Plan.pdf

APPENDIX E - SO2 Modeling Parameters 

Facility Name: Minnesota Power – Laskin Energy Center 

Permit Number: 13700013-006 

** MN Power - Laskin Energy Center - SO2 Modeling *** 05/30/02 

 

 *** *** *** *** *** *** POINT SOURCE DATA *** *** *** *** *** 

 

 NO. EMISSION COORD COORD BASE STACK STACK STACK STACK 

 SOURCE PART. RATE X Y ELEV. HEIGHT TEMP. EXIT VEL DIAMETER 

 ID CATS. (G/S) (M) (M) (M) (M) (DEG.K) (M/SEC) (M) 

Scenario S01 LECSV001 0 3.40E+02 563085 5264402 442.2 91.4 330.8 14.5 3.2 

Scenario S02 LECSV001 0 2.55E+02 563085 5264402 442.2 91.4 326.3 10.9 3.2 

Scenario S03 LECSV001 0 1.70E+02 563085 5264402 442.2 91.4 321.9 7.2 3.2 

Scenario S04 LECSV001 0 1.70E+02 563085 5264402 442.2 91.4 321.9 7.2 3.2 

Scenario S05 LECSV001 0 1.28E+02 563085 5264402 442.2 91.4 317.4 5.4 3.2 

Scenario S06 LECSV001 0 8.50E+01 563085 5264402 442.2 91.4 313 3.6 3.2 

 

 

APPENDIX F - NOX and PM10 Modeling Parameters 

Facility Name: Minnesota Power – Laskin Energy Center 

Permit Number: 13700013-006 

 ** MN Power - Laskin Energy Center - NOx Modeling *** 06/13/02 

 

 *** *** *** *** *** *** POINT SOURCE DATA *** *** *** *** 

 NUMBER EMISSION COORD COORD BASE STACK STACK STACK STACK 

 SOURCE PART. RATE X Y ELEV. HEIGHT TEMP. EX VEL DIA. 

 ID CATS. (G/S) (M) (M) (M) (M) (DEG.K) (M/SEC) (M) 

Scenario N01 LECSV001 0 8.32E+01 563085 5264402 442.2 91.4 330.8 14.5 3.2 

Scenario N02 LECSV001 0 6.24E+01 563085 5264402 442.2 91.4 326.3 10.9 3.2 

Scenario N03 LECSV001 0 4.16E+01 563085 5264402 442.2 91.4 321.9 7.2 3.2 

Scenario N04 LECSV001 0 4.16E+01 563085 5264402 442.2 91.4 321.9 7.2 3.2 

Scenario N05 LECSV001 0 3.13E+01 563085 5264402 442.2 91.4 317.4 5.4 3.2 

Scenario N06 LECSV001 0 2.08E+01 563085 5264402 442.2 91.4 313 3.6 3.2 

 *** *** *** *** *** *** *** *** *** *** *** *** *** *** *** *** *** *** *** *** *** 

 

 ** MN Power - Laskin Energy Center - PM10 Modeling *** 06/09/02 

 *** *** *** *** *** *** POINT SOURCE DATA *** *** *** *** 

 NUMBER EMISSION COORD COORD BASE STACK STACK STACK STACK 

 SOURCE PART. RATE X Y ELEV. HEIGHT TEMP. 

EXIT 

VEL DIA. 

 ID CATS. (G/S) (M) (M) (M) (M) (DEG.K) (M/SEC) (M) 

Scenario P01 LECSV001 0 9.98E+01 563085 5264402 442.2 91.4 330.8 14.5 3.2 

Scenario P02 LECSV001 0 7.48E+01 563085 5264402 442.2 91.4 326.3 10.9 3.2 

Scenario P03 LECSV001 0 4.99E+01 563085 5264402 442.2 91.4 321.9 7.2 3.2 

Scenario P04 LECSV001 0 4.99E+01 563085 5264402 442.2 91.4 321.9 7.2 3.2 

Scenario P05 LECSV001 0 3.74E+01 563085 5264402 442.2 91.4 317.4 5.4 3.2 

Scenario P06 LECSV001 0 2.50E+01 563085 5264402 442.2 91.4 313 3.6 3.2 

 

 *** *** *** *** *** *** VOLUME SOURCE DATA *** *** *** *** 

 NUMBER EMISSION COORD COORD BASE RELEASE INIT. INIT. 

 SOURCE PART. RATE X Y ELEV. HEIGHT SY SZ 

 ID CATS. (G/S) (M) (M) (M) (M) (M) (M) 

Scenario P01-P06 LECSV002 0 3.97E-03 563186.1 5264463 441.6 16.76 0.85 9.91 

Scenario P01-P06 LECSV009 0 1.19E-02 563079.9 5264381 442.2 11.9 0.14 5.52 

 

 

 ** MN Power - Laskin Energy Center - PM10 Modeling parameters continued on next page *** 

 

 

 

 
*** *** *** *** *** *** AREA SOURCE DATA *** *** *** *** *** *** 

 NUMBER EMISSION COORD COORD BASE RELEASE X-DIM Y-DIM ORIENT. 

 SOURCE PART. RATE X Y ELEV. HEIGHT OF AREA AREA AREA 

 ID CATS. (G/S/M^2) (M) (M) (M) (M) (M) (M) (DEG.) 

Scenario P01-P06 LECFS101 0 6.99E-07 563210.1 5264430 440.3 7.01 79 180 8 

Scenario P01-P06 LECFS201 0 7.08E-06 563210.1 5264430 440.3 7.01 79 180 8 

Scenario P01-P06 LECFS202 0 7.11E-06 562515.9 5264566 445.2 0 20.1 20.1 0 

Scenario P01-P06 LECFS301 0 3.63E-07 563210.1 5264430 440.3 7.01 79 180 8 

Scenario P01-P06 LECFS302 0 1.62E-07 562242.8 5264649 443.1 3 50.8 10 -38 

Scenario P01-P06 LECFS303 0 1.62E-07 562282.8 5264680.5 444.3 3 72 10 -45.7 

Scenario P01-P06 LECFS304 0 1.62E-07 562333.4 5264732 446.1 3 28.5 10 -31.3 

Scenario P01-P06 LECFS305 0 1.62E-07 562357.8 5264747 447 3 43.6 10 2.5 

Scenario P01-P06 LECFS306 0 1.62E-07 562401.2 5264745 449.2 3 100 10 17.7 

Scenario P01-P06 LECFS307 0 1.62E-07 562496.1 5264714.5 450.7 3 100 10 17.1 

Scenario P01-P06 LECFS308 0 1.62E-07 562591.4 5264685.5 450.7 3 100 10 19.6 

Scenario P01-P06 LECFS309 0 1.62E-07 562685.3 5264652 451.3 3 100 10 24.6 

Scenario P01-P06 LECFS310 0 1.62E-07 562643.4 5264562 452.8 3 100 10 -57.2 

Scenario P01-P06 LECFS311 0 1.62E-07 562633.8 5264541 452.8 3 23 10 -65.7 

Scenario P01-P06 LECFS312 0 1.62E-07 562541.8 5264550.5 451.3 3 83.3 10 4.6 

Scenario P01-P06 LECFS313 0 1.62E-07 562775.8 5264610 451.3 3 100 10 21.9 

Scenario P01-P06 LECFS314 0 1.62E-07 562868.9 5264573 448.3 3 100 10 30.5 

Scenario P01-P06 LECFS315 0 1.62E-07 562955.3 5264522.5 445.2 3 80 10 -7.9 

Scenario P01-P06 LECFS316 0 1.62E-07 563034.9 5264533.5 442.2 3 100 10 -5.2 

Scenario P01-P06 LECFS317 0 1.62E-07 562212.6 5264714.5 442.2 3 495.6 227 -90 

Scenario P01-P06 LECFS318 0 1.62E-07 562016 5264454.5 445.2 3 526 157.2 -0.2 

Scenario P01-P06 LECFS319 0 1.62E-07 562238 5264658 443.1 3 10 63 -33 

Scenario P01-P06 LECFS401 0 6.31E-08 561969.4 5263083 447.3 3 53.9 10 -53.8 

Scenario P01-P06 LECFS402 0 6.31E-08 562001.2 5263126.5 449.2 3 100 10 -84.8 

Scenario P01-P06 LECFS403 0 6.31E-08 562010.8 5263226 451.6 3 100 10 -71.5 

Scenario P01-P06 LECFS404 0 6.31E-08 562044.8 5263322.5 452.2 3 100 10 -69.6 

Scenario P01-P06 LECFS405 0 6.31E-08 562079.9 5263416.5 451.3 3 100 10 -69.9 

Scenario P01-P06 LECFS406 0 6.31E-08 562114.4 5263510.5 451.3 3 100 10 -69.2 

Scenario P01-P06 LECFS407 0 6.31E-08 562150.7 5263604.5 448.3 3 45.7 10 -66.2 

Scenario P01-P06 LECFS408 0 6.31E-08 562169.1 5263646.5 446.7 3 51.2 10 -52.5 

Scenario P01-P06 LECFS409 0 6.31E-08 562199.7 5263687 445.2 3 100 10 -41.3 

Scenario P01-P06 LECFS410 0 6.31E-08 562274.9 5263753.5 446.7 3 100 10 -40 

Scenario P01-P06 LECFS411 0 6.31E-08 562351.8 5263817.5 448.3 3 100 10 -37.4 

Scenario P01-P06 LECFS412 0 6.31E-08 562431 5263878.5 446.1 3 100 10 -38.6 

Scenario P01-P06 LECFS413 0 6.31E-08 562509 5263941 446.1 3 59.4 10 -51.1 

Scenario P01-P06 LECFS414 0 6.31E-08 562546.9 5263987.5 443.7 3 100 10 -61.5 

Scenario P01-P06 LECFS415 0 6.31E-08 562594.2 5264075.5 447.3 3 100 10 -63.6 

Scenario P01-P06 LECFS416 0 6.31E-08 562638.2 5264165 446.1 3 27.2 10 -80.5 

Scenario P01-P06 LECFS417 0 6.31E-08 562642.2 5264191.5 446.1 3 84 10 -95.7 

Scenario P01-P06 LECFS418 0 6.31E-08 562633.8 5264275 447 3 28.1 10 -72.6 

Scenario P01-P06 LECFS419 0 6.31E-08 562642.7 5264301 449.2 3 34 10 -38 

Scenario P01-P06 LECFS420 0 6.31E-08 562669.6 5264322 449.2 3 92 10 -15 

Scenario P01-P06 LECFS421 0 6.31E-08 562758.5 5264346 447.3 3 100 10 -1 

Scenario P01-P06 LECFS422 0 6.31E-08 562858.6 5264347 445.2 3 100 10 -9.3 

Scenario P01-P06 LECFS423 0 6.31E-08 562957.2 5264362.5 443.7 3 100 10 -8.5 

Scenario P01-P06 LECFS424 0 6.31E-08 563055.7 5264377.5 442.2 3 62.9 10 -10.2 

Scenario P01-P06 LECFS425 0 6.31E-08 563117.6 5264389 441.6 3 44.2 10 -40.7 

Scenario P01-P06 LECFS426 0 6.31E-08 563151.6 5264418 440.9 3 42.5 10 -69.8 

Scenario P01-P06 LECFS427 0 6.31E-08 563166.3 5264458.5 440.3 3 88.9 10 -108.2 

Scenario P01-P06 LECFS428 0 6.31E-08 563043.7 5264386 442.2 3 18.7 10 -99.9 

Scenario P01-P06 LECFS429 0 6.31E-08 563039.4 5264404 442.2 3 62.3 30 -97.2 

Scenario P01-P06 LECFS501 0 2.78E-04 563195.6 5264561 442.2 1.5 4.6 12.8 8 
Technical Support Document, Permit Action Number: 13700013-006 

Page 1 of 7 

Date: 1/7/2009 

TECHNICAL SUPPORT DOCUMENT

For 

AIR EMISSION PERMIT NO. 13700013-006

This Technical Support Document (TSD) is for all parties interested in the permit and meets the 

requirements of 40 CFR § 70.7(a)(5) and Minn. R. 7007.0850, subp. 1. This document provides the legal 

and factual justification for each applicable requirement or policy decision considered in the preliminary 

determination to issue the permit. 

1 General Information 

1.1 Applicant and Stationary Source Location

Applicant/Address Stationary Source/Address 

(SIC Code: 4911) 

Minnesota Power Division of ALLETE, Inc. 

30 West Superior Street 

Duluth, MN 55802-2093 

Laskin Energy Center 

5699 Colby Lake Rd 

Hoyt Lakes, St. Louis County, MN 55750 

Contact: Brandon Krogh 

Senior Engineer 

218-723-3954

1.2 Facility Description 

This facility is composed of two electric utility steam boilers, each rated at 660 mmBtu/hr. Each boiler 

has twelve 4 mmBtu/hr gas/oil-fired ignitors and dry low NOX combustors. Each boiler vents emissions 

to a high-efficiency wet scrubber that discharges to the atmosphere through a common stack. The 

scrubbers control PM, PM10, SO2, and lead. Net electric production is 55 MW per boiler. 

Boiler ratings were previously listed as 660 mmBtu/hr for bituminous coal and 525 for sub-bituminous 

coal. However, the Permittee states the 525 mmBtu/hr capacity was measured in the 1980s using old wet 

sub-bituminous coal, and that 660 mmBtu/hr can be achieved when combusting dry sub-bituminous coal. 

1.3 Description of the Current Permit Action and All Amendments Issued since the Last Total 

Facility Permit 

This permit is a reissuance of the Part 70 operating permit. Two administrative amendments, submitted 

April 6, 2007 and May 30, 2008, requesting extensions for performance tests were incorporated with this 

permit issuance. No other changes are authorized by this permit action. 

Permit Number and Issuance Date Action Authorized

13700013-002 

March 5, 1999 

Addition of the NOx requirements to the Phase II Acid Rain 

portion of the Title V operating permit 

13700013-003 

June 4, 2002 

Replacement of the distillate oil-fired ignitors in Boilers 1 and 

2 with ignitors that can burn distillate oil and natural gas 

13700013-004 Permit not issued 

13700013-005 

September 18, 2006 

Install low-NOX burners and overfire air controls on Boilers 1 

and 2 
Technical Support Document, Permit Action Number: 13700013-006 

Page 2 of 7 

Date: 1/7/2009 

1.4 Facility Emissions 

Table 1 - Total Facility Potential to Emit Summary 1

 PM 

tpy 

PM10

tpy 

SO2

tpy 

NOX

tpy 

CO 

tpy 

VOC 

tpy 

Total HAP 

tpy 

Total Facility Limited 

Potential Emissions 

1,488 341 2,865 997 630 18.2 353.4 

Total Facility Actual 

Emissions (2007) 

298 298 1,341 932 100 12.0 HAPs not reported in 

emission inventory 

1

Limited emissions based on 12-month rolling sum 630 tpy CO emission limit excluding insignificant sources. 

Table 2 - Facility Classification 

Classification Major/Affected Source Synthetic Minor Minor 

PSD PM, PM10, SO2, NOX, CO VOC 

Part 70 Permit Program PM10, SO2, NOX, CO VOC 

Part 63 NESHAP Single & Total HAP 

1.5 Changes to Permit 

No significant changes have been made to the requirements in the permit. The following changes have 

been made: 

• the permit has been updated to reflect current MPCA policy, templates and standard citation 

formatting; 

• completed requirements and the requirements for equipment that has been removed have been 

deleted; 

• performance test frequency plan has been incorporated; 

• Continuous Emissions Monitoring System (CEMS) Relative Accuracy Test Audit requirements have 

been moved from emission units to monitors; 

• compliance assurance monitoring (CAM) plan requirements have been added to the permit; and 

• the requirement to update the fugitive dust control plan has been removed. 
Technical Support Document, Permit Action Number: 13700013-006 

Page 3 of 7 

Date: 1/7/2009 

2 Regulatory and/or Statutory Basis

New Source Review

The facility is an existing major source under New Source Review regulations. No changes are 

authorized by this permit.

Part 70 Permit Program

The facility is a major source under the Part 70 permit program. 

New Source Performance Standards (NSPS)

There are no New Source Performance Standards applicable to the operations at this facility. 

National Emission Standards for Hazardous Air Pollutants (NESHAP)

There are no NESHAPs applicable to the operations at this facility. 

Acid Rain Program

Both boilers, EU 001 and EU 002, are subject to the acid rain program requirements to monitor and report 

SO2, NOX, and CO2 emissions and to hold sufficient SO2 allowances for SO2 emissions. 40 CFR Part 75 

offers several monitoring provisions in addition to the general operating requirements (CEMS), and 

alternative monitoring systems under Subpart E. The acid rain permit application is included in the permit 

as Appendix B. 

Compliance Assurance Monitoring (CAM)

This permit action is a re-issuance of a Part 70 permit. Therefore CAM applies to any emission units with 

air pollution control equipment which meet the CAM applicability requirements. 40 CFR Part 64 

requires CAM for emission units that meet the following criteria: 

• The unit is subject to an emission limitation or standard for the applicable regulated air pollutant, 

• The unit uses a control device to achieve compliance, and 

• The unit has potential pre-control device emissions of the pollutant that are equal to or greater than 

100 percent of the amount, in tons per year, required for the source to be classified as a major source. 

The Permittee uses add-on controls (wet scrubbers) to reduce emissions from both boilers to meet 

emission limits for PM, NOX and SO2. The facility satisfies the requirements of CAM for NOX and SO2

through the use of CEMS to measure NOX and SO2. The wet scrubbers (CE 001 and CE 002) for boilers 

1 and 2 (EU 001 and EU 002) are subject to CAM for PM only. The CAM plan is included in the permit 

as Appendix D. 

To assure compliance with the PM emission limit, scrubber exhaust temperature and opacity will be 

monitored. Scrubber exhaust temperature was selected as an indicator because it is indicative of the 

scrubber operation and appropriate scrubber water flow. Opacity was selected as an indicator because 

performance testing has demonstrated that opacity is a limiting pollutant with respect to PM emissions; 

opacity will exceed the opacity limit before PM will exceed the PM limit. Monitoring systems for 

temperature and opacity are located in the common stack at the 150-foot stack elevation. 

Minnesota State Rules

The two steam-electric boilers are subject to PM, SO2, and opacity limits in Minn. R. 7011.0510 

Standards of Performance for Existing Indirect Heating Equipment. The coal crusher is subject to the PM 

and opacity limits in Minn. R. 7011.0715 Standards of Performance for Industrial Process Equipment.

Table 3 - Regulatory Overview of Units 
Technical Support Document, Permit Action Number: 13700013-006 

Page 4 of 7 

Date: 1/7/2009 

EU, GP, 

or SV 

Applicable Regulations Comments: 

GP 001 Title I Condition: to avoid major 

modification under §52.21 and/or 

§52.21(r)(6) for CO 

CO limits, monitoring, and recordkeeping to 

avoid PSD and Minnesota Environmental 

Review requirements. 

GP 002 40 CFR pt. 64 CAM requirements: the scrubbers are used to 

comply with the Standards of Performance for 

Indirect Heating Equipment PM limit, and the 

uncontrolled potential from each of the boilers 

is greater than 100 tpy, so CAM applies. 

EU 001 

and 

EU 002 

Title I Condition: to avoid major 

modification under § 52.21 and/or 

§52.21(r)(6) for CO 

Minn. R. 7007.0800, subp. 2; this is a 

state-only requirement not enforceable by 

the EPA administrator or citizens under the 

Clean Air Act 

Minn. R. 7011.0510 Standards of 

Performance for Indirect Heating 

Equipment 

Acid Rain requirements

CO emission factor limit, monitoring, 

recordkeeping, and testing to avoid PSD and 

Minnesota Environmental Review 

requirements. 

NOX limit: The Permittee secured a rate rider 

to pay for the NOX controls as a part of the 

Arrowhead Regional Emissions Abatement 

(AREA) plan. This ensures the rate payer gets 

the reduced emissions for the additional cost 

of electricity. 

PM, SO2 and Opacity standards. 

The acid rain permit application is included as 

an appendix to the permit. Some requirements 

are listed in Table A of the permit. 

EU 003 Minn. R. 7011.0715 Standards of 

Performance for Post-1969 Industrial 

Process Equipment 

Opacity and PM standards. 

SV 001 Minn. Stat. Section 116.07, subds. 4a & 9; 

Minn. R. 7007.0100, subps. 7A, 7L & 7M; 

Minn. R. 7007.0800, subps. 1, 2 & 4; 

Minn. R. 7009.0010-7009.0080; this is a 

state-only requirement not enforceable by 

the EPA Administrator or citizens under 

the Act. 

SO2 limit (lower than applicable performance 

standard) based on Title V modeling. The 

most recently modeled parameters are 

included in Appendix E to the permit and the 

Permittee must receive written approval prior 

to making changes to the parameters. 
Technical Support Document, Permit Action Number: 13700013-006 

Page 5 of 7 

Date: 1/7/2009 

3 Technical Information

3.1 Emission Analysis and Calculations 

Attachment 1 to this TSD contains the summary of the permitted PTE of the Facility and detailed 

spreadsheets with supporting information prepared by the MPCA and the Permittee. 

3.2 Periodic Monitoring 

In accordance with the Clean Air Act, it is the responsibility of the owner or operator of a facility to have 

sufficient knowledge of the facility to certify that the facility is in compliance with all applicable 

requirements. 

In evaluating the monitoring included in the permit, the MPCA considers the following: 

• The likelihood of violating the applicable requirements; 

• Whether add-on controls are necessary to meet the emission limits; 

• The variability of emissions over time; 

• The type of monitoring, process, maintenance, or control equipment data already available for the 

emission unit; 

• The technical and economic feasibility of possible periodic monitoring methods; and 

• The kind of monitoring found on similar units elsewhere. 

Table 4 summarizes the periodic monitoring requirements for those emission units for which the 

monitoring required by the applicable requirement is nonexistent or inadequate. 

Table 4 - Periodic Monitoring 

Emission 

Unit or 

Group 

Requirement 

(basis) 

Additional 

Monitoring 

Discussion 

GP 001 CO emission factor ≤0.126 

lb/mmBtu 

OR 

CO ≤630 tpy on a 12-month 

rolling sum basis 

(Title I Condition to avoid 

major modification under 

§52.21) 

CO stack testing to 

verify emission 

factor, CO ppm 

emissions indicator, 

and monthly 

calculation of 12-

month CO emissions 

if factor >0.126 

lb/mmBtu. 

The Permittee has two options for 

demonstrating the CO emissions 

increase is not significant. The first 

option requiring the verification of the 

CO factor has less recordkeeping than 

the second option of meeting a 12-month 

rolling sum CO limit. Both options 

restrict the CO increase to less than the 

100 tpy significant level. 

EU 001 

and 

EU 002 

NOX ≤0.20 lb/mmBtu on a 

365-day rolling average 

(Minn. R. 7007.0800, subp. 2) 

NOX is measured by 

a CEMS on the 

common stack 

This is a state-only requirement not 

enforceable by the EPA administrator or 

citizens under the Clean Air Act. The 

Permittee secured a rate rider to pay for 

the NOX controls. This ensures the rate 

payer gets the reduced emissions for the 

additional cost of electricity. 
Technical Support Document, Permit Action Number: 13700013-006 

Page 6 of 7 

Date: 1/7/2009 

Emission 

Unit or 

Group 

Requirement 

(basis) 

Additional 

Monitoring 

Discussion 

PM ≤0.60 lb/mmBtu 

(Minn. R. 7011.0510) 

Control equipment 

has a CAM plan to 

ensure control 

efficiency. 

PM limit from Standards of Performance 

for Existing Indirect Heating Equipment. 

Opacity ≤20% 

(Minn. R. 7011.0510) 

Opacity is monitored 

by a COMS on the 

common stack . 

Opacity limit from Minnesota Standards 

of Performance for Existing Indirect 

Heating Equipment. 

SO2 ≤4.0mmBtu - solid fuels 

SO2 ≤2.0mmBtu – liquid fuels 

(Minn. R. 7011.0510) 

SO2 is measured by a 

CEMS on the 

common stack. 

SO2 limit for each emission unit for solid 

and liquid fuels from Minnesota 

Standards of Performance for Existing 

Indirect Heating Equipment. 

SV 001 SO2 ≤2.04 mmBtu 

(Minn. Stat. § 116.07, subds. 

4a & 9; Minn. R. 7007.0100, 

subps 7A, 7L & 7M; Minn. R. 

7007.0800, subps. 1, 2 & 4; 

Minn. R. 7009.0010-

7009.0080) 

SO2 is measured by a 

CEMS on the 

common stack. 

SO2 limit on the common stack (lower 

than applicable performance standard) is 

based on title V modeling. This is a 

state-only requirement not enforceable 

by the EPA Administrator or citizens 

under the Act. 

3.3 Comments Received 

Public Notice Period: October 4, 2008 – November 3, 2008 

EPA 45-day Review Period: October 4, 2008 - November 18, 2008 
Technical Support Document, Permit Action Number: 13700013-006 

Page 7 of 7 

Date: 1/7/2009 

4 Conclusion 

Based on the information provided by Minnesota Power Division of ALLETE, Inc., the MPCA has 

reasonable assurance that the operation of the emission facility, as described in the Air Emission Permit 

No. 13700013-006 and this technical support document, will not cause or contribute to a violation of 

applicable federal regulations and Minnesota Rules. 

Staff Members on Permit Team: Adriane Lenshek (permit writer/engineer) 

 Steve Palzkill, (enforcement) 

 Andy Place (stack testing) 

 Chris Buntjer (peer reviewer) 

Attachments: 1. PTE Summary and Calculation Spreadsheets 

2. Facility Description and CD-01 Forms 

AQ File No. 73D; DQ 101, 1467, 1545; ID: 13700013
 
Attachment 1 - PTE Summary and Calculation Spreadsheets 

Attachment 2 - Facility Description and CD-01 Forms 

OMB 2060-0631 Part I Question 14a

Minnesota Power Laskin Energy Center (1891)Materials listed in the permit

Laskin "Other" Materials Permitted to burn Actual

(yes

Boiler cleaning agents (EDTA type and Ammonium Bromate), generated on-site

5% of total fuel mass, oxygen limited to 3% or greater, agents may only be burned while the boiler is operating at 75 percent of rated capacity or greater. *

Non-hazardous petroleum distillate solvents and derived fuels NA nUsed oil 720 gallons/hour and 2,500,000 gallons annually of off-specification and on-specification used oi Y

Oily coal (coal with oil spilled on it) NA nOily cellulose-based sorbents (including rags) 1.25 tons per hour and 25 tons per year (on a 12-month rolling sum basis) nBoiler cleaning agents (EDTA type and Ammonium Bromate), generated on-site

5% of total fuel mass, oxygen limited to 3% or greater, agents may only be burned while the boiler is operating at 75 percent of rated capacity or greater. *

Non-hazardous petroleum distillate solvents and derived fuels NA nUsed oil

Fuel Usage: less than or equal to 720 gallons/hour and less than 2,500,000 gallons annually of off-specification and on-specification used oil. Used oil shall be burnedin 

accordance with Minn. R. ch. 7045.

Y

Oily coal (coal with oil spilled on it) NA nOily cellulose-based sorbents (including rags) 1.25 tons per hour and 25 tons per year (on a 12-month rolling sum basis) n

* Permitted to burn but have yet to execise that option at LEC

NA=no specific numerical limit listed in permit for this material

Unit 1Unit 2

If "other" was checked in questions 10 or 11 above indicating that any non-fossil fuel or other material (including, but not limited to, plastics, treated wood, rubber belting or fuel, boiler cleaning solutions, animal wastes, etc.) is either utilized or permitted to be used, please indicate below what materials are combusted in the boiler and in what qquantity is on a weight percentage or heat [Btu] basis). Also indicate (yes/no) whether you are permitted to burn non-fossil fuel(s) or other material(s) even if you do not ac
OMB 2060-0631 Part I, Question 15: Identification (or designation) of all coal- and oil-fired steam generating units (boilers) (as defined by Clean Air Act section 112(2)

Minnesota Power Laskin Energy Center (1891)

Facility Name

Subpart EIA Plant CodeQ 15.01 Boiler ID Unit 1 Unit 2Q 15.02 Original design fuel (i.e. coal rank or type of oil) Bituminous coal or oil Bituminous coal or oilQ 15.03 Design heat input (mmBtu/hr)1 501 501

Q 15.04 Present maximum heat input, (mmBtu/hr) 3 725 660Q 15.05 MWe gross capacity summer 60 55Q 15.06 MWe net capacity summer 55.8 50.7Q 15.07 Original design gross efficiency (%, HHV) 87.8 (12,150btu/lb) 87.8 (12,150btu/lb)Q 15.08 Present operating gross efficiency (%, HHV)4 NA NA

Q 15.09 Design steam pressure (psig)1 1250 1250Q 15.10 Operating steam pressure (psig) 1250 1250Q 15.11 Design steam temperature (°F)1 950 950

Q 15.12 Operating steam temperature (°F) 950 950Q 15.13 Design steam reheat temperature (°F)5 NA NA

Q 15.14 Operating steam reheat temperature (°F)5 NA NAQ 15.15 FuelQ 15.16 Hours/year operated 7494.86 7744.33Q 15.17 Average annual capacity factor for the past 3 years 61.56 64.05Q 15.18 Applicable NSPSQ 15.19 Estimated year of retirement Minnesota Power has no scheduled or planned retirement dates for any of our units

1Original design values based on boiler acquisition contracts and/or heat balance drawings. Design heat input value does not represent maximum capacity at the time 2Each Laskin unit was originally built as 44MWn nominal. The units were upgraded to 55MWn output in the mid-1960s.

Laskin units are permitted to burn either eastern bituminous coal or a combination of western sub-bituminous coal with oil topping. Sub-bituminous coal is now the prim

3Current heat input data from Title V permit application does not represent maximum heat input capacity.4We do not measure or calculate boiler efficiency on either unit at this facility. 5Units do not have a steam reheat cycle.

LASKIN2

1891

 40 CFR Part 60 Subpart Y 

>99% coal, <1%other
OMB 2060-0631 Part I, Question 16: Emission Control Technology

Minnesota Power Laskin Energy Center (1891)Designate the order of the emission controls -- 1 for first control following the boiler, 2 for second control following the boiler, etc.

Plant ID Boiler ID Type NOx Control In-service Date SO2 Control In-service Date PM Control In-s

D

Laskin 1 Tangentially-fired 1 - Low NOx burners 2007 2 - Wet particulate scrubber 1971 2 - Wet particulate scrubber 1

1891 2 Tangentially-fired 1 - Low NOx burners 2006 2 - Wet particulate scrubber 1971 2 - Wet particulate scrubber 1
OMB 2060-0631 Part I, Question 22: Guaranteed Emission Rate

Minnesota Power Laskin Energy Center (1891)

PM PM10 PM2.5 SO2 HCl and/or HF HCN Metal HAP Hg CO 

1 0.03 grains/ACF Baseline + 1002 0.03 grains/ACF Baseline + 100

Laskin

Most recent guaranteed emission rate for each pollutant for which there is a permitted emission lim

Plant ID Boiler ID
OMB 2060-063 Part II Questions 2-3

Coal Shipments - Minnesota Power Laskin Energy Center (1891)

Train ID Tons Boiler ID# State County Coal Seam

Fuel 

Ship 

Method Sulfur Ash Btu/Lb Mercury Chlorine Fluorine N

DKMVIL301 1,2 MT Big Horn Dietz 1 and Dietz 2 RR 0.370 4.100 9,265 N/A N/A N/A N

DKMVIL302 1,2 MT Big Horn Dietz 1 and Dietz 3 RR 0.420 4.410 9,304 N/A N/A N/A NDKMVIL303 1,2 MT Big Horn Dietz 1 and Dietz 4 RR 0.380 4.200 9,498 N/A N/A N/A NDKMVIL304 1,2 MT Big Horn Dietz 1 and Dietz 5 RR 0.420 4.490 9,346 N/A N/A N/A NDKMVIL305 1,2 MT Big Horn Dietz 1 and Dietz 6 RR 0.420 4.640 9,386 N/A N/A N/A NDKMVIL306 1,2 MT Big Horn Dietz 1 and Dietz 7 RR 0.370 3.990 9,370 N/A N/A N/A NDKMVIL307 1,2 MT Big Horn Dietz 1 and Dietz 8 RR 0.430 4.710 9,287 N/A N/A N/A NDKMVIL308 1,2 MT Big Horn Dietz 1 and Dietz 9 RR 0.420 4.770 9,377 N/A N/A N/A NDKMVIL309 1,2 MT Big Horn Dietz 1 and Dietz 10 RR 0.390 4.800 9,222 N/A N/A N/A NDKMVIL310 1,2 MT Big Horn Dietz 1 and Dietz 11 RR 0.320 3.880 9,267 N/A N/A N/A NDKMVIL311 1,2 MT Big Horn Dietz 1 and Dietz 12 RR 0.460 4.850 9,549 N/A N/A N/A NDKMVIL312 1,2 MT Big Horn Dietz 1 and Dietz 13 RR 0.520 5.460 9,349 N/A N/A N/A NDKMVIL313 1,2 MT Big Horn Dietz 1 and Dietz 14 RR 0.460 3.810 9,666 N/A N/A N/A NDKMVIL314 1,2 MT Big Horn Dietz 1 and Dietz 15 RR 0.320 3.530 9,591 N/A N/A N/A NDKMVIL315 1,2 MT Big Horn Dietz 1 and Dietz 16 RR 0.340 3.850 9,577 N/A N/A N/A NDKMVIL316 1,2 MT Big Horn Dietz 1 and Dietz 17 RR 0.390 4.480 9,331 N/A N/A N/A NDKMVIL317 1,2 MT Big Horn Dietz 1 and Dietz 18 RR 0.380 4.470 9,375 N/A N/A N/A NDKMVIL318 1,2 MT Big Horn Dietz 1 and Dietz 19 RR 0.400 5.140 9,258 N/A N/A N/A NDKMVIL319 1,2 MT Big Horn Dietz 1 and Dietz 20 RR 0.480 5.080 9,449 N/A N/A N/A NDKMVIL320 1,2 MT Big Horn Dietz 1 and Dietz 21 RR 0.280 3.060 9,705 N/A N/A N/A NDKMVIL321 1,2 MT Big Horn Dietz 1 and Dietz 22 RR 0.300 3.990 9,278 N/A N/A N/A NDKMVIL322 1,2 MT Big Horn Dietz 1 and Dietz 23 RR 0.460 3.940 9,357 N/A N/A N/A NDKMVIL323 1,2 MT Big Horn Dietz 1 and Dietz 24 RR 0.390 4.670 9,252 N/A N/A N/A NDKMVIL324 1,2 MT Big Horn Dietz 1 and Dietz 25 RR 0.420 4.090 9,530 N/A N/A N/A N

BTMVIL101 12,083.200 1,2 WY Campbell N/A RR 0.220 4.360 8,982 N/A N/A N/A NBTMVIL102 11,477.500 1,2 WY Campbell N/A RR 0.310 5.230 8,834 N/A N/A N/A NETMVIL101 9,780.900 1,2 WY Carbon N/A RR 0.590 10.720 10,748 N/A N/A N/A NATMVIL101 11,597.325 1,2 WY Converse N/A RR 0.260 5.950 8,778 N/A N/A N/A NATMVIL102 12,341.050 1,2 WY Converse N/A RR 0.260 5.990 8,763 N/A N/A N/A NOil Shipments - Laskin Energy Center

OMB 2060-063 Part II Questions 2-3

ID Gallons State County

Coal 

Seam Fuel Ship Method Sulfur Ash Btu/Lb Mercury Chlorine Fluorine Nickel O

No deliveries of oil received for boiler usage at Laskin Energy Center.

11,223.00012,670.00012,569.00012,651.00012,463.00010,300.00012,154.00011,681.00012,344.00012,356.000

Fuel Source

11,628.00012,468.00012,300.00010,505.00012,875.00010,816.00011,022.00012,362.00012,360.00012,265.00010,842.00011,949.00011,809.00011,864.000
OMB 2060-0631 Part II, Question 8a, 8b, 8f

Minnesota Power Laskin Energy Center (1891)Boiler ID(as listed in Part I question 15)

Question 8a Emission test report, parametric monitoring data, or other data or monitoring

Question 8bDate of testing

Question 8bType of testing

Question 8bConstituents

Question 8fDid the unit's control configuration differ for that shown in Part I, questions 16 at the time of the test? Boiler ID

Boiler 1 and Boiler 2 GE Energy

Carbon Monoxide Emissions Engineering Study

3/16/2006 stack CO yes

B1 & B2 

Boiler 1 and Boiler 2 GE Energy

Emission Compliance Study

7/24-25/2007 stack CO no

Boiler 1 and Boiler 2 GE Energy

Emission Compliance Study

2/27/2007 & 7/24/2007 stack PM no

Boiler 1 and Boiler 2 Platt Environmental Services, 

IncMercury Testing

6/30/2008 stack mercury no

Boiler 1 and Boiler 2 GE Energy

PM Correlation Emission Study

2/24-26/2009 & 3/2-3/2009 stack PM no

Boiler 1 and Boiler 2 GE Energy

Emission Compliance Study

7/7/2009 stack PM and CO no

Boiler 1 and Boiler 2 GE Energy

Mercury Emission Study

7/7/2009 stack mercury no
OMB 2060-0631 Part II, Question 12

Minnesota Power Laskin Energy Center (1891)Boiler ID Test Date PM* SO2 HCL/HF/HCN Metal HAP Hg* CO* Other organic

Unit Load (MW)

Net MWH NET)

Moisture(%) Flow

(dscfm or Nm3/hr)

Boiler 1 and Boiler 2 3/16/2006 Unit 1 & 2 = 0.108 lb/mmBtu

Unit 1 & 2 = 93.28 lb.hr

99.93 310,370 dscfm 

Boiler 1 and Boiler 2 GE Energy

Emission Compliance Study

Unit 1 coal = 0.056 lb/mmBtu coal/fuel oil = 0.033 lb/mmBtu coal/nat gas = 0.043 lb/mmBtuUnit 2 coal = 0.096 lb/mmBtu coal/fuel oil = 0.077 lb/mmBtu coal/nat gas = 0.042 lb/mmBtu

Unit 1 coal = 51.9 coal/fuel oil = 53.7 coal/nat gas = 53.4Unit 2 coal = 51.1 coal/fuel oil = 53.7 coal/nat gas = 51.7

Boiler 1 and Boiler 2 GE Energy

Emission Compliance Study

Coal only = 0.08 lb/mmBtuCoal/Fuel oil = 0.07 lb/mmBtu

Coal only = 109.3Coal/Fuel oil = 109.3

Coal only = 5.0Coal/Fuel oil = 10.2

Coal only = 325,867 dscfCoal/Fuel oil = 302,539 d

Boiler 1 and Boiler 2 6/30/2008 Total Hg = 0.32 ppb 90.9 10.6 Boiler 1 and Boiler 2 2/24-26/2009 and 3/2-3/20021 samples for filterable PM concentrations 94.3 5.6 301,180 dscfm 

Boiler 1 and Boiler 2 7/7/2009 Unit 1 & 2 filterable PM = 0.05 lb/mmBtu

Unit 1 CO = 0.005 lb/mmBtuUnit 2 CO = 0.004 lb/mmBtu

PM test = 107.2CO test = 107.1

PM test = 7.4 353,080 dscfm 

Boiler 1 and Boiler 2 11/17/2009Boiler 1 and Boiler 2 7/7/2009 Run 1 = 8.360E-10 lb/dscf

Run 2 = 8.339E-10 lb/dscfRun 3 = 8.315E-10 lb/dscf

107.53 

* Averaging Time = 3 - 1 hour rounds

TDD (for hearing and speech impaired only): (651) 282-5332 

Printed on recycled paper containing at least 10% fibers from paper recycled by consumers 

AIR EMISSION PERMIT NO. 03100001- 008 

Major Amendment 

IS ISSUED TO

MINNESOTA POWER DIVISION OF ALLETE INC 

Cliffs Erie LLC 

Minnesota Power - Tac Harbor Energy Ctr 

8124 West Highway 61 

Schroeder, Cook County, MN 55613 

The emission units, control equipment and emission stacks at the stationary source authorized in 

this permit amendment are as described in the Permit Applications Table. 

This permit amendment supersedes Air Emission Permit No. 03100001-007 and authorizes the 

Permittee to operate the stationary source at the address listed above unless otherwise noted in 

Table A. The Permittee must comply with all the conditions of the permit. Any changes or 

modifications to the stationary source must be performed in compliance with Minn. R. 

7007.1150 to 7007.1500. Terms used in the permit are as defined in the state air pollution control 

rules unless the term is explicitly defined in the permit. 

Unless otherwise indicated, all the Minnesota rules cited as the origin of the permit terms are 

incorporated into the State Implementation Plan under 40 CFR § 52.1220 and as such are 

enforceable by U.S. Environmental Protection Agency (EPA) Administrator or citizens under the 

Clean Air Act. 

Permit Type: Federal; Pt 70/Limits to Avoid NSR; 

Major Amendment Issue Date: October 19, 2009 

Expiration Date: 04/07/2004*– Title I Conditions do not expire.

*The Permittee may continue to operate this facility after the expiration date of the permit, per 

the provision under Minn. R. 7007.0450, subp. 3. (Title V Reissuance Application was received 

10/10/2003. 

 

 Don Smith, P.E., Manager 

 Air Quality Permits Section 

 Industrial Division 

 

 for Paul Eger 

 Commissioner 

 Minnesota Pollution Control Agency 

Permit Applications Table

Permit Type Application Date Issue Date Action 

Total Facility Operating Permit June 14, 1995 May 19, 1997 001 

Major Amendment November 30, 1998 April 7, 1999 002 

Major Amendment March 23, 2006 January 8, 2007 006 

Major Amendment January 18, 2008 May 20, 2008 007 

Major Amendment October 10, 2008 NA 008 

TABLE OF CONTENTS 

Notice to the Permittee 

Permit Shield 

Facility Description 

Amendment Description

Table A: Limits and Other Requirements 

Table B: Submittals 

Appendices 

NOTICE TO THE PERMITTEE: 

Your stationary source may be subject to the requirements of the Minnesota Pollution Control 

Agency’s (MPCA) solid waste, hazardous waste, and water quality programs. If you wish to 

obtain information on these programs, including information on obtaining any required permits, 

please contact the MPCA general information number at: 

 Metro Area 651-296-6300 

 

 Outside Metro Area 1-800-657-3864 

 TTY 651-282-5332 

The rules governing these programs are contained in Minn. R. chs. 7000-7105. Written questions 

may be sent to: Minnesota Pollution Control Agency, 520 Lafayette Road North, St. Paul, 

Minnesota 55155-4194. 

Questions about this air emission permit or about air quality requirements can also be directed to 

the telephone numbers and address listed above. 

PERMIT SHIELD:

Subject to the limitations in Minn. R. 7007.1800, compliance with the conditions of this permit 

shall be deemed compliance with the specific provision of the applicable requirement identified 

in the permit as the basis of each condition. Subject to the limitations of Minn. R. 7007.1800 and 

7017.0100, subp. 2, notwithstanding the conditions of this permit specifying compliance 

practices for applicable requirements, any person (including the Permittee) may also use other 

credible evidence to establish compliance or noncompliance with applicable requirements. 
FACILITY DESCRIPTION: 

Minnesota Power’s Taconite Harbor Energy Center consists of three 75 megawatt (net) coal-fired 

units located in Schroeder, Minnesota. The units have tangentially fired boilers that are permitted 

to burn both bituminous and sub-bituminous coals. Coal for the boilers is stored in an outdoor 

storage pile. Prior to the coal being conveyed to the boilers it is crushed. The crusher is located in 

a building that currently is not vented to the atmosphere. This permit action is to allow the crusher 

building to be vented to the atmosphere through a fabric filter for dust collection. Since the 

crusher had previously not been vented to the atmosphere, it was not listed as an emission unit in 

the existing operating permit. This permit action will add the coal crusher and conveyor transfer 

points to the operating permit as an emission unit. The fabric filter serving the ventilation will be 

added as control equipment to the permit with requirements to limit opacity. 

AMENDMENT DESCRIPTION:

03100001-002 

This permit action allows the Permittee to discontinue operation of their Total Suspended 

Particulate (TSP) ambient air quality monitors. The original Title V permit (Air Emission Permit 

No. 03100001-001) had a condition that allowed for the discontinuation after one more year of 

continued ambient compliance shown by the monitors. The one more year of continued 

compliance was shown and the Permittee has applied for the permit change. It should also be 

noted that the original monitors showed no violations for three (3) plus years of monitoring prior 

to permit issuance. 

03100001-006 

This permit authorizes installation of additional pollution controls on boiler No. 2. The project is 

one of the Permittee’s Arrowhead Regional Emissions Abatement (AREA) emission reduction 

projects and will result in voluntary emission reductions not required by rule or statute. The 

Permittee has received approval from the Minnesota Public Utilities Commission to recapture 

costs from its customer base that are associated with the project. 

The Permittee proposes to install Nitrogen Oxides (NOX), Sulfur Dioxide (SO2), and mercury 

controls on boiler No. 2 as a pilot test to ensure efficacy of the control technology. The control 

technology known as “Mobotec” is a multi-pollutant control technology. The Mobotec mercury 

control system is a developing technology than has not been previously installed on 

subbituminous coal-fired boilers. 

03100001-007 

This permit action is a major permit amendment because it increases the emissions of particulate 

from coal preparation and triggers a Standard of Performance for Coal Preparation Plants 

(40 CFR pt. 60 subp. Y). The modification allowed by this permit action is the addition of 

existing coal crusher and coal conveyor transfer points as an emission unit controlled by a fabric 

filter dust collection system. This permit action also incorporates an administrative amendment 

to extend the initial performance test deadline for Boiler No. 2 (EU 002) an additional 120 days. 
03100001-008 

No physical changes will occur as part of this permit amendment. The permit amendment is 

primarily a revision to the State-Only (Non Title-I) emission limits of SO2 and NOX for EU002. 

In 2006, Minnesota Power installed Mobotec’s multi pollution control technologies as a pilot test 

project on Taconite Harbor Unit 2 boiler to reduce SO2, NOX, and Mercury. There was a 

possibility of a significant increase in Particulate Matter (PM) and Particulate Matter smaller 

than 10 mincrons (PM10) emissions due to the injection of lime based alkali into the boiler for 

SO2 control. There were various permit conditions put in the permit to avoid a significant 

increase of PM and PM10 under Prevention of Significant Deterioration Program. This permit 

amendment revises the state-only emissions limits due to uncertainties surrounding the control 

devices and technologies involved. It has proven necessary to operate the control system at a 

reduced hydrate injection rate in order to reliably meet the PM and PM10 limits. These reduced 

injection rates has caused the facility to be unable to achieve the level of SO2 expected by the 

pilot project. Likewise, the actual efficiency of the NOX reduction system is slightly less then 

anticipated. The revised emissions limits are 0.45 lbs/MMBtu SO2 and 0.17 lbs/MMBtu NOX. 

This permit amendment allows the facility to discontinue use of molten sulfur ejection as an 

Electrostatic Precipitator conditioning agent. Molten sulfur has been shown to have an inverse 

relationship with mercury removal. Stack tests have also shown that the facility can meet 

particulate limits without the use of Sulfur Trioxide injection. 

TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-1

Table A contains limits and other requirements with which your facility must comply. The limits are located in the first column of

the table (What To do). The limits can be emission limits or operational limits. This column also contains the actions that you must

take and the records you must keep to show that you are complying with the limits. The second column of Table A (Why to do it)

lists the regulatory basis for these limits. Appendices included as conditions of your permit are listed in Table A under total facility

requirements.

Subject Item: Total Facility

What to do Why to do it

DETERMINING IF A PROJECT/MODIFICATION IS SUBJECT TO NEW SOURCE

REVIEW

hdr

These requirements apply where there is a reasonable possibility that a proposed

project, analyzed using the actual-to-projected-actual (ATPA) test and found to

not be part of a major modification, may result in a significant emissions increase.

If the ATPA test is not used for a particular project, or if there is not a reasonable

possibility that the proposed project could result in a significant emissions

increase, then these requirements do not apply to that project.

Even though a particular modification is not subject to New Source Review,

a permit amendment, recordkeeping, or notification may still be required under

Minn. R. 7007.1150 - 7007.1500.

Title I Condition: 40 CFR Section 52.21(r)(6) and

Minn. R. 7007.3000

Preconstruction Documentation -- Before beginning actual construction on a

project, the Permittee shall document the following information:

1. A description of the project

2. Identification of the emission unit(s) whose emissions of an NSR pollutant could

 be affected

3. A description of the applicability test used to determine that the project is not

 a major modification for any regulated NSR pollutant, including the baseline

 actual emissions, the potential emissions, the projected actual emissions, the

 amount of emissions excluded due to increases not associated with the

 modification and that the unit(s) could have accommodated during the baseline

 period, an explanation of why the amounts were excluded, and any creditable

 contemporaneous increases and decreases that were considered in the

 determination.

The Permittee shall maintain records of this documentation.

Title I Condition: 40 CFR Section 52.21(r)(6) and

Minn. R. 7007.3000;

Minn. R. 7007.0800, subps. 4 & 5

The Permittee shall monitor the actual emissions of any regulated NSR pollutant

that could increase as a result of the project and that were analyzed using the

ATPA test, and the potential emissions of any regulated NSR pollutant that could

increase as a result of the project and that were analyzed using potential

emissions. The Permittee shall calculate and maintain a record of the sum of the

actual and potential (if used in the analysis) emissions of the regulated pollutant, in

tons per year on a calendar year basis, for a period of 5 years following resumption

of regular operations after the change, or for a period of 10 years following

resumption of regular operations after the change if the project increases the

design capacity of or potential to emit of any unit associated with the project.

Title I Condition: 40 CFR Section 52.21(r)(6) and

Minn. R. 7007.3000;

Minn. R. 7007.0800, subps. 4 & 5

Before beginning actual construction of any project which includes any electric

utility steam generating unit (EUSGU), the Permittee shall submit a copy of the

preconstruction documentation (items 1-3 under Preconstruction Documentation,

above) to the Agency.

Title I Condition: 40 CFR Section 52.21(r)(6) and

Minn. R. 7007.3000;

Minn. R. 7007.0800, subps. 4 & 5

For any project which includes any EUSGU, the Permittee must submit an annual

report to the Agency, within 60 days after the end of the calendar year. The report

shall contain:

1. The name and ID number of the facility, and the name and telephone number

 of the facility contact person

2. The quantified annual emissions analyzed using the ATPA test, plus the

 potential emissions associated with the same project and analyzed using

 potential emissions

3. Any other information, such as an explanation as to why the summed

 emissions differ from the preconstruction projection, if that is the case.

Title I Condition: 40 CFR Section 52.21(r)(6) and

Minn. R. 7007.3000;

Minn. R. 7007.0800, subps. 4 & 5
TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-2

For any project which does not include any EUSGU, the Permittee must submit a

report to the Agency if the annual summed (actual plus potential, if applicable)

emissions differ from the preconstruction projection and exceed the baseline actual

emissions by a significant amount as listed at 40 CFR Section 52.21(b)(23). Such

report shall be submitted to the Agency within 60 days after the end of the year in

which the exceedances occur. The report shall contain:

1. The name and ID number of the facility, and the name and telephone number

 of the facility contact person

2. The annual emissions (actual plus potential, if any part of the project was

 analyzed using potential emissions) for each pollutant for which the

 preconstruction projection and significant emissions rate is exceeded.

3. Any other information, such as an explanation as to why the summed

 emissions differ from the preconstruction projection.

Title I Condition: 40 CFR Section 52.21(r)(6) and

Minn. R. 7007.3000;

Minn. R. 7007.0800, subps. 4 & 5

OPERATING REQUIREMENTS hdr

The Permittee shall comply with National Primary and Secondary Ambient Air

Quality Standards, 40 CFR pt. 50, and the Minnesota Ambient Air Quality

Standards, Minn. R. 7009.0010 to 7009.0080. Compliance shall be demonstrated

upon written request by the MPCA.

40 CFR pt. 50;

Minn. Stat. Section 116.07, subds. 4a & 9;

Minn. R. 7007.0100, subps. 7A, 7L & 7M;

Minn. R. 7007.0800, subps. 1, 2 & 4;

Minn. R. 7009.0010 - 7009.0080

The Permittee shall comply with the General Conditions listed in Minn. R.

7007.0800, subp. 16.

Minn. R. 7007.0800, subp. 16

Fugitive Emissions: Do not cause or permit the handling, use, transporting,

or storage of any material in a manner which may allow avoidable amounts

of particulate matter to become airborne. Comply with all other requirements

listed in Minn. R. 7011.0150.

Minn. R. 7011.0150

Comply with Fugitive Emissions Control Plan: Follow the actions and

recordkeeping specified in the control plan. The plan may be amended with the

Commissioner's approval. If the Commissioner determines that you are out of

compliance with Minn. R. 7011.0150 or the control plan, then you may be required

to amend the control plan. The Commissioner may also require re-installation and

operation of particulate matter ambient air monitors.

Minn. R. 7007.0800, subp. 2

Air Pollution Control Equipment: Operate all pollution control equipment whenever

the corresponding process equipment and emission units are operated, unless

otherwise noted in Table A.

Minn. R. 7007.0800, subps. 2 & 16(J)

Operation and Maintenance Plan: Retain at the stationary source an operation and

maintenance plan for all air pollution control equipment. At a minimum, the O&M

plan shall identify all air pollution control equipment and control practices and shall

include a preventative maintenance program for the equipment and practices, a

description of (the minimum but not necessarily the only) corrective actions to be

taken to restore the equipment and practices to proper operation to meet applicable

permit conditions, a description of the employee training program for proper

operation and maintenance of the control equipment and practices, and the

records kept to demonstrate plan implementation.

Minn. R. 7007.0800, subps. 14 & 16(J)

Noise: The Permittee shall comply with noise standards set forth in Minn. R.

7030.0010 to 7030.0080 at all times during operation of any emission units.

This is a state requirement only and is not federally enforceable.

Minn. R. 7030.0010 - 7030.0080

Operation of Monitoring Equipment: Unless otherwise noted in Tables A and/or B,

monitoring a process or control equipment connected to that process is not

necessary during periods when the process is shutdown, such as for system

breakdowns, repairs, calibration checks, and zero and span adjustments (as

applicable). Monitoring records should reflect any such periods of process

shutdown.

Minn. R. 7007.0800, subp. 4(D)

Monitoring Equipment Calibration: Annually calibrate all required monitoring

equipment (any requirements applying to continuous emission monitors are listed

separately in this permit).

Minn. R. 7007.0800, subp. 4(D)

Circumvention: Do not install or use a device or means that conceals or dilutes

emissions, which would otherwise violate a federal or state air pollution control rule,

without reducing the total amount of pollutant emitted.

Minn. R. 7011.0020

Inspections: The Permittee shall comply with the inspection procedures and

requirements as found in Minn. R. 7007.0800, subp. 9(A).

Minn. R. 7007.0800, subp. 9(A)

PERFORMANCE TESTING hdr

Performance Testing: Conduct all performance tests in accordance with Minn. R.

ch. 7017 unless otherwise noted in Tables A and/or B.

Minn. R. ch. 7017
TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-3

Performance Test Notifications and Submittals:

Performance Tests are due as outlined in Tables A and B of the permit.

See Table B for additional testing requirements.

Performance Test Notification (written): due 30 days before each Performance Test

Performance Test Plan: due 30 days before each Performance Test

Performance Test Pre-test Meeting: due 7 days before each Performance Test

Performance Test Report: due 45 days after each Performance Test

Performance Test Report - CD Copy: due 105 days after each Performance Test

The Notification, Test Plan, and Test Report may be submitted in alternative format

as allowed by Minn. R. 7017.2018.

Minn. R. 7017.2018;

Minn. R. 7017.2030, subps. 1-4;

Minn. R. 7017.2035, subps. 1-2

Limits set as a result of a performance test (conducted before or after permit

issuance) apply until superseded as stated in the MPCA's Notice of Compliance

letter granting preliminary approval. Preliminary approval is based on formal review

of a subsequent performance test on the same unit as specified by Minn. R.

7017.2025, subp. 3. The limit is final upon issuance of a permit amendment

incorporating the change.

Minn. R. 7017.2025, subp. 3

RECORDKEEPING hdr

Recordkeeping: Retain all records at the stationary source for a period of five (5)

years from the date of monitoring, sample, measurement, or report. Records which

must be retained at this location include all calibration and maintenance records, all

original strip-chart recordings for continuous monitoring instrumentation, and copies

of all reports required by the permit. Records must conform to the requirements

listed in Minn. R. 7007.0800, subp. 5(A).

Minn. R. 7007.0800, subp. 5(C)

Recordkeeping: Maintain records describing any insignificant modifications (as

required by Minn. R. 7007.1250, subp. 3) or changes contravening permit terms

(as required by Minn. R. 7007.1350, subp. 2), including records of the emissions

resulting from those changes.

Minn. R. 7007.0800, subp. 5(B)

If the Permittee determines that no permit amendment or notification is required

prior to making a change, the Permittee must retain records of all calculations

required under Minn. R. 7007.1200. These records shall be kept for a period of five

years from the date the change was made or until permit reissuance, whichever is

longer. The records shall be kept at the stationary source for the current calendar

year of operation and may be kept at the office of the stationary source for all other

years. The records may be maintained in either electronic or paper format.

Minn. R. 7007.1200, subp. 4

NOTIFICATIONS AND SUBMITTALS hdr

Notification of Deviations Endangering Human Health or the Environment:

As soon as possible after discovery, notify the Commissioner or the state duty

officer, either orally or by facsimile, of any deviation from permit conditions which

could endanger human health or the environment.

Minn. R. 7019.1000, subp. 1

Notification of Deviations Endangering Human Health or the Environment Report:

Within 2 working days of discovery, notify the Commissioner in writing of any

deviation from permit conditions which could endanger human health or the

environment. Include the following information in this written description:

1. The cause of the deviation;

2. The exact dates of the period of the deviation, if the deviation has been

 corrected;

3. Whether or not the deviation has been corrected;

4. The anticipated time by which the deviation is expected to be corrected,

 if not yet corrected; and

5. Steps taken or planned to reduce, eliminate, and prevent reoccurrence

 of the deviation.

Minn. R. 7019.1000, subp. 1

Shutdown Notifications: Notify the Commissioner at least 24 hours in advance of a

planned shutdown of any control equipment or process equipment if the shutdown

would cause any increase in the emissions of any regulated air pollutant. If the

owner or operator does not have advance knowledge of the shutdown, notification

shall be made to the Commissioner as soon as possible after the shutdown.

However, notification is not required in the circumstances outlined in Items A, B,

and C of Minn. R. 7019.1000, subp. 3.

At the time of notification, the owner or operator shall inform the Commissioner of

the cause of the shutdown and the estimated duration. The owner or operator shall

notify the Commissioner when the shutdown is over.

Minn. R. 7019.1000, subp. 3
TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-4

Breakdown Notifications: Notify the Commissioner within 24 hours of a breakdown

of more than one hour duration of any control equipment or process equipment if

the breakdown causes any increase in the emissions of any regulated air pollutant.

The 24-hour time period starts when the breakdown was discovered or reasonably

should have been discovered by the owner or operator. However, notification is not

required in the circumstances outlined in Items A, B, and C of Minn. R. 7019.1000,

subp. 2.

At the time of notification or as soon as possible thereafter, the owner or operator

shall inform the Commissioner of the cause of the breakdown and the estimated

duration. The owner or operator shall notify the Commissioner when the

breakdown is over.

Minn. R. 7019.1000, subp. 2

Application for Permit Amendment: If you need a permit amendment, submit

application in accordance with the requirements of Minn. R. 7007.1150-7007.1500.

Submittal dates vary, depending on the type of amendment needed.

Minn. R. 7007.1150 - 7007.1500

Extension Requests: The Permittee may apply for an Administrative Amendment to

extend a deadline in a permit by no more than 120 days, provided the proposed

deadline extension meets the requirements of Minn. R. 7007.1400, subp. 1(H).

Minn. R. 7007.1400, subp. 1(H)

Emission Fees: due 60 days after receipt of an MPCA bill Minn. R. 7002.0005 - 7002.0095

Emission Inventory Report: due on or before April 1 of each calendar year following

permit issuance. To be submitted this on a form approved by the Commissioner.

Minn. R. 7019.3000 - 7019.3010

At the present time, the permittee must comply with all the applicable requirements

in 40 CFR pt. 97 for a CAIR NOx source, a CAIR SO2 source, a CAIR NOx unit,

and a CAIR SO2 unit as defined in 40 CFR Sections 97.102 and 97.202.

If the US Environmental Protection Agency promulgates a rule to stay 40 CFR pt.

97 in Minnesota, this requirement will be of no further force and no longer in effect

upon the effective date of the rule.

40 CFR pt. 97; 40 CFR Section 52.1240; Minn. R.

7007. 0800, subp. 2.

Water flow rate: less than or equal to 5.0 gallons/minute of coal pile run off.

this limit is based on a submittal by the permittee that shows that the additional Btu

input required to boil off this coal pile rain water run off does not constute a

significant increase in emission.

This permittee shall not dispose of the coal pile rain water run off in this manner if

this meathod voilates any other permit that the facilty holds or other Minnesota law.

Minn. R. 7007.0800, subp. 3
TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-5

Subject Item: GP 001 Three 745 MMBtu/hr coal-fired boilers

Associated Items: EU 001 Boiler No. 1

EU 002 Boiler No. 2

EU 003 Boiler No. 3

What to do Why to do it

Total GP 001 Sulfur Dioxide: less than or equal to 1743 lbs/hour using 3-hour

Average

Minn. R. 7009.0020 to avoid causing or contributing to

a violation of the SO2 ambient air quality standards in

Minn. R. 7009.0080

Mercury content of coal: Less than or equal to 0.20 parts per million on an annual

average basis. The agency will refrain from enforcement action for exceedance of

this mercury limit if the Permittee is able to demonstrate, to the satisfaction of the

agency, that the Permittee has used best efforts to comply with the mercury limit.

Minn. R. 7007.0800, subp. 2

Coal sampling for mercury content: Collect a daily coal sample, and analyze a

composite sample of the coal at least once a week according to the most current

ASTM method (currently ASTM Method D-6722). The Permittee shall maintain a

record of all analyses for at least 5 years from the date of analysis. Results of the

analyses shall be reported semiannually with the Semiannual Deviations Report.

Minn. R. 7007.0800, subp. 2

Boiler Cleaning Agents: The Permittee is authorized to incinerate boiler cleaning

agents in any of the three boilers. Boiler cleaning agents are limited to EDTA type

and Ammonium bromate, must be generated on-site, can not exceed 5 percent of

total fuel mass input, and oxygen must be to 3 percent or greater. Agents may only

be burned while the boiler is operating at 75 percent of rated capacity or greater.

Minn. R. 7007.0800, subp. 2
TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-6

Subject Item: GP 002 Reagent Handling and Storage

Associated Items: CE 013 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

CE 014 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

CE 015 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

EU 008 Alkaline Reagent Silo (SV 008/CE 013)

EU 009 Mercury Reagent Silo (SV 009/CE 014)

EU 010 Trona Silo (SV 010/CE 015)

What to do Why to do it

Total Particulate Matter: less than or equal to 0.01 grains/dry standard cubic foot for

each GP 002 emission unit.

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000;

meets requirements of Minn. R. 7011.0735

Particulate Matter < 10 micron: less than or equal to 0.01 grains/dry standard cubic

foot for each GP 002 emission unit.

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000

Opacity: less than or equal to 20 percent opacity for each GP 002 emission unit. Minn. R. 7011.0715, subp. 1.B

The Permittee shall operate and maintain each fabric filter so that it achieves an

overall control efficiency for filterable Total Particulate Matter: greater than or equal

to 99 percent control efficiency

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000;

Minn. R. 7007.0800, subps. 2 & 14

The Permittee shall operate and maintain each fabric filter so that it achieves an

overall control efficiency for filterable PM < 10 micron: greater than or equal to 99

percent control efficiency

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000;

Minn. R. 7007.0800, subps. 2 & 14

The Permittee shall operate and maintain each fabric filter at all times that any

emission unit controlled by the fabric filter is in operation.

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000;

Minn. R. 7007.0800, subps. 2 & 14

Visible Emissions: The Permittee shall check the CE 013, CE 014, and CE 015

stack/vent for any visible emissions during each delivery to the emission unit

storage silo controlled by the fabric filter, but not more frequently than once each

calendar week for a specific storage silo.

A calendar week starts each Sunday. All observations shall be made during

daylight hours.

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000;

Minn. R. 7007.0800, subps. 2 & 14

Recordkeeping of Visible Emissions: The Permittee shall record the time and date

of each visible emission inspection and whether or not any visible emissions were

observed.

Title I Condition: To avoid classification as a major

source and modification under 40 CFR Section 52.21

and Minn. R. 7007.3000;

Minn. R. 7007.0800, subps. 4 & 5

Periodic Inspections: The Permittee shall inspect the fabric filter components once

per calendar quarter or as required by the manufacturer. The Permittee shall

maintain a written record of these inspections.

Minn. R. 7007.0800, subps. 4, 5, & 14

Corrective Actions: The Permittee shall take corrective action as soon as possible

if any of the following occur:

1. Visible emissions are observed;

2. During an inspection, the fabric filter or any of its components are found to

 need repair.

Corrective actions shall eliminate visible emissions, and/or include completion of

necessary repairs identified during the inspection, as applicable. Corrective actions

include, but are not limited to, those outlined in the O&M Plan for the fabric filter.

The Permittee shall keep a record of the type and date of any corrective action

taken for each filter.

Minn. R. 7007.0800, subps. 4, 5, & 14
TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-7

Subject Item: GP 003 Hauling on Paved Roads

Associated Items: CE 016 Paved Road Sweeping

FS 009 Mercury Reagent Truck Hauling - Paved Road

FS 010 Alkaline (or Trona) Reagent Truck Hauling - Paved Road

FS 011 Molten Sulfur Truck Hauling - Paved Road

FS 012 Ammonia Truck Hauling - Paved Road

FS 013 Urea Truck Hauling - Paved Road

What to do Why to do it

Paved Haul Road Fugitive Emissions Control: The Permittee shall follow the

practices described in the revised fugitive emissions control plan, for control of

fugitive emissions from GP 003 fugitive emission sources. The practices at a

minimum shall include sweeping of paved road surfaces at the frequency specified

in the revised plan.

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000
TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-8

Subject Item: GP 004 Pellet and Material Handling

Associated Items: FS 001 Pellet Drop From Railcars into Dock Storage Bins

FS 005 Ship Loading of Taconite Pellets

FS 006 Railcar Material Loading

What to do Why to do it

The Permittee shall follow the practices described in the revised fugitive emissions

control plan for control of fugitive emissions from GP 004 fugitive emission sources,

if these sources become active.

Minn. R. 7007.0800, subp. 2
TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-9

Subject Item: SV 001 Boiler 1 stack

Associated Items: EU 001 Boiler No. 1

MR 028 COMS

MR 029 SO2 Monitor

MR 030 NOx Monitor

MR 031 CO2 Monitor

MR 032 Flow Monitor

What to do Why to do it

COMS REQUIREMENTS hdr

Emissions Monitoring: The owner or operator shall measure the opacity of the

emission unit using a COMS.

40 CFR Section 75.10;

Minn. R. 7017.1006

All COMS shall complete a minimum of one cycle of sampling and analyzing for

each successive 10-second period and one cycle of data for each successive

6-minute period.

Minn. R. 7017.1200, subps. 1, 2 & 3

Continuous Operation: COMS must be operated and data recorded during all

periods of emission unit operation including periods of emission unit start-up,

shutdown, or malfunction except for periods of acceptable monitor downtime. This

requirement applies whether or not a numerical emission limit applies during these

periods. A COMS must not be bypassed except in emergencies where failure to

bypass would endanger human health, safety, or plant equipment.

Acceptable monitor downtime includes reasonable periods as listed in Items A, B,

C and D of Minn. R. 7017.1090, subp. 2.

Minn. R. 7017.1090, subp. 1

COMS Daily Calibration Drift Check: The Permittee must automatically, intrinsic to

the opacity monitor, check the zero and upscale (span) calibration drifts at least

once daily. The span value shall be between 60% and 80%. The optical surfaces

exposed to the effluent gases shall be cleaned prior to performing the zero and

span drift adjustments. The optical surfaces shall be cleaned when the cumulative

automatic zero compensation exceeds 4 percent opacity.

Minimum procedures must include an automated method for producing a simulated

zero opacity condition and an upscale opacity condition as specified in 40 CFR

60.13(d)(2).

Minn. R. 7017.1210, subp. 2

COMS Calibration Error Audit: due before end of each calendar half-year following

Permit Issuance. Conduct three point calibration error audits at least 3 months

apart but no greater than 8 months apart. Conduct audits in accordance with Minn.

R. 7017.1210, subp. 3.

Minn. R. 7017.1210, subp. 3

Attenuator Calibration: The Permittee shall have an independent testing company

conduct calibrations of each of the neutral density filters used in the calibration

error audit according to the procedure in 40 CFR Part 60, Appendix B, Section

7.1.3.1 within the time frame of opacity stability guaranteed by the attenuator

manufacturer. The manufacturer's guarantee of stability shall be available on-site

for inspection.

Minn. R. 7017.1210, subp. 4

COMS Calibration Error Audit Results Summary: due 30 days after end of each

calendar quarter in which the COMS calibration error audit was completed.

Minn. R. 7017.1220

Recordkeeping: The owner or operator must retain records of all COMS monitoring

data and support information for a period of five years from the date of the

monitoring sample, measurement or report. Records shall be kept at the source.

Minn. R. 7017.1130

PART 75 CEMS REQUIREMENTS hdr

Emissions Monitoring: The owner or operator shall measure opacity, SO2, NOx,

and CO2 emissions and flow rate for each affected unit in accordance with 40 CFR

Section 75.10.

40 CFR Section 75.10

Daily Calibration Error (CE) Test: Conduct daily CE testing on all CEMS required

by the Acid Rain Program, in accordance with 40 CFR pt. 75, Appendix B.

40 CFR pt. 75, Appendix B, section 2.1

Linearity and Leak Check Test (Acid Rain Program): due before end of each QA

operating quarter (as defined in Section 72.) in accordance with procedures in 40

CFR pt. 75, Appendix B, Sections 2.2.1 and 2.2.2, and Appendix A, Section 6.2.

Perform a leak check at least once during each QA operating quarter (calendar

quarter in which there are at least 168 unit operating hours) and no less than 30

days apart.

40 CFR pt. 75, Appendix B, sections 2.2.1 & 2.2.2;

Minn. R. 7017.1020

Linearity Test Results Summary: due 30 days after end of each calendar quarter

following Linearity and Leak Check Test if performed.

Minn. R. 7017.1180, subp. 4
TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-10

CEMS Relative Accuracy Test Audit (RATA): due before end of each calendar

half-year following CEM Certification Test, i.e., once every two successive QA

operating quarters (calendar quarter in which there are at least 168 unit operating

hours). Conduct a RATA on all CEMS required by the Acid Rain Program, in

accordance with 40 CFR pt. 75, Appendix B. Relative accuracy test audits may be

performed annually (i.e., once every four successive QA operating quarters, rather

than once every two successive QA operating quarters) if any of the conditions

listed in 40 CFR pt. 75, Appendix B, Section 2.3.1.2(a) through Section 2.3.1.2(i)

are met.

40 CFR pt. 75, Appendix B, section 2.3.1;

Minn. R. 7017.1020

Relative Accuracy Test Audit (RATA) Notification: due 30 days before CEMS

Relative Accuracy Test Audit (RATA)).

Minn. R. 7017.1180, subp. 2

Relative Accuracy Test Audit (RATA) Results Summary: due 30 days after end of

each calendar quarter in which the CEMS RATA was conducted.

Minn. R. 7017.1180, subp. 3

CEMS QA/QC: The owner or operator of an affected facility shall operate,

calibrate, and maintain each CEMS according to the QA/QC procedure in 40 CFR

pt. 75, Appendix B as amended.

40 CFR Section 75.21

Recordkeeping: The owner or operator must retain records of all CEMS monitoring

data and support information for a period of five years from the date of the

monitoring sample, measurement or report. Records shall be kept at the source.

40 CFR Section 75.50;

Minn. R 7017.1130
TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-11

Subject Item: SV 002 Boiler 2 stack

Associated Items: EU 002 Boiler No. 2

MR 033 COMS

MR 034 SO2 Monitor

MR 035 NOx Monitor

MR 036 CO2 Monitor

MR 037 Flow Monitor

What to do Why to do it

COMS REQUIREMENTS hdr

Emissions Monitoring: The owner or operator shall measure the opacity of the

emission unit using a COMS.

40 CFR Section 75.10;

Minn. R. 7017.1006

All COMS shall complete a minimum of one cycle of sampling and analyzing for

each successive 10-second period and one cycle of data for each successive

6-minute period.

Minn. R. 7017.1200, subps. 1, 2 & 3

Continuous Operation: COMS must be operated and data recorded during all

periods of emission unit operation including periods of emission unit start-up,

shutdown, or malfunction except for periods of acceptable monitor downtime. This

requirement applies whether or not a numerical emission limit applies during these

periods. A COMS must not be bypassed except in emergencies where failure to

bypass would endanger human health, safety, or plant equipment.

Acceptable monitor downtime includes reasonable periods as listed in Items A, B,

C and D of Minn. R. 7017.1090, subp. 2.

Minn. R. 7017.1090, subp. 1

COMS Daily Calibration Drift Check: The Permittee must automatically, intrinsic to

the opacity monitor, check the zero and upscale (span) calibration drifts at least

once daily. The span value shall be between 60% and 80%. The optical surfaces

exposed to the effluent gases shall be cleaned prior to performing the zero and

span drift adjustments. The optical surfaces shall be cleaned when the cumulative

automatic zero compensation exceeds 4 percent opacity.

Minimum procedures must include an automated method for producing a simulated

zero opacity condition and an upscale opacity condition as specified in 40 CFR

60.13(d)(2).

Minn. R. 7017.1210, subp. 2

COMS Calibration Error Audit: due before end of each calendar half-year following

Permit Issuance. Conduct three point calibration error audits at least 3 months

apart but no greater than 8 months apart. Conduct audits in accordance with Minn.

R. 7017.1210, subp. 3.

Minn. R. 7017.1210, subp. 3

Attenuator Calibration: The Permittee shall have an independent testing company

conduct calibrations of each of the neutral density filters used in the calibration

error audit according to the procedure in 40 CFR Part 60, Appendix B, Section

7.1.3.1 within the time frame of opacity stability guaranteed by the attenuator

manufacturer. The manufacturer's guarantee of stability shall be available on-site

for inspection.

Minn. R. 7017.1210, subp. 4

COMS Calibration Error Audit Results Summary: due 30 days after end of each

calendar quarter in which the COMS calibration error audit was completed.

Minn. R. 7017.1220

Recordkeeping: The owner or operator must retain records of all COMS monitoring

data and support information for a period of five years from the date of the

monitoring sample, measurement or report. Records shall be kept at the source.

Minn. R. 7017.1130

PART 75 CEMS REQUIREMENTS hdr

Emissions Monitoring: The owner or operator shall measure opacity, SO2, NOx,

and CO2 emissions and flow rate for each affected unit in accordance with 40 CFR

Section 75.10.

40 CFR Section 75.10

Daily Calibration Error (CE) Test: Conduct daily CE testing on all CEMS required

by the Acid Rain Program, in accordance with 40 CFR pt. 75, Appendix B.

40 CFR pt. 75, Appendix B, section 2.1

Linearity and Leak Check Test (Acid Rain Program): due before end of each QA

operating quarter (as defined in Section 72.) in accordance with procedures in 40

CFR pt. 75, Appendix B, Sections 2.2.1 and 2.2.2, and Appendix A, Section 6.2.

Perform a leak check at least once during each QA operating quarter (calendar

quarter in which there are at least 168 unit operating hours) and no less than 30

days apart.

40 CFR pt. 75, Appendix B, sections 2.2.1 & 2.2.2;

Minn. R. 7017.1020

Linearity Test Results Summary: due 30 days after end of each calendar quarter

following Linearity and Leak Check Test if performed.

Minn. R. 7017.1180, subp. 4
TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-12

CEMS Relative Accuracy Test Audit (RATA): due before end of each calendar

half-year following CEM Certification Test, i.e., once every two successive QA

operating quarters (calendar quarter in which there are at least 168 unit operating

hours). Conduct a RATA on all CEMS required by the Acid Rain Program, in

accordance with 40 CFR pt. 75, Appendix B. Relative accuracy test audits may be

performed annually (i.e., once every four successive QA operating quarters, rather

than once every two successive QA operating quarters) if any of the conditions

listed in 40 CFR pt. 75, Appendix B, Section 2.3.1.2(a) through Section 2.3.1.2(i)

are met.

40 CFR pt. 75, Appendix B, section 2.3.1;

Minn. R. 7017.1020

Relative Accuracy Test Audit (RATA) Notification: due 30 days before CEMS

Relative Accuracy Test Audit (RATA)).

Minn. R. 7017.1180, subp. 2

Relative Accuracy Test Audit (RATA) Results Summary: due 30 days after end of

each calendar quarter in which the CEMS RATA was conducted.

Minn. R. 7017.1180, subp. 3

CEMS QA/QC: The owner or operator of an affected facility shall operate,

calibrate, and maintain each CEMS according to the QA/QC procedure in 40 CFR

pt. 75, Appendix B as amended.

40 CFR Section 75.21

Recordkeeping: The owner or operator must retain records of all CEMS monitoring

data and support information for a period of five years from the date of the

monitoring sample, measurement or report. Records shall be kept at the source.

40 CFR Section 75.50;

Minn. R 7017.1130
TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-13

Subject Item: SV 003 Boiler 3 stack

Associated Items: EU 003 Boiler No. 3

MR 038 COMS

MR 039 SO2 Monitor

MR 040 NOx Monitor

MR 041 CO2 Monitor

MR 042 CO2 Monitor

MR 043 Flow Monitor

What to do Why to do it

COMS REQUIREMENTS hdr

Emissions Monitoring: The owner or operator shall measure the opacity of the

emission unit using a COMS.

40 CFR Section 75.10;

Minn. R. 7017.1006

All COMS shall complete a minimum of one cycle of sampling and analyzing for

each successive 10-second period and one cycle of data for each successive

6-minute period.

Minn. R. 7017.1200, subps. 1, 2 & 3

Continuous Operation: COMS must be operated and data recorded during all

periods of emission unit operation including periods of emission unit start-up,

shutdown, or malfunction except for periods of acceptable monitor downtime. This

requirement applies whether or not a numerical emission limit applies during these

periods. A COMS must not be bypassed except in emergencies where failure to

bypass would endanger human health, safety, or plant equipment.

Acceptable monitor downtime includes reasonable periods as listed in Items A, B,

C and D of Minn. R. 7017.1090, subp. 2.

Minn. R. 7017.1090, subp. 1

COMS Daily Calibration Drift Check: The Permittee must automatically, intrinsic to

the opacity monitor, check the zero and upscale (span) calibration drifts at least

once daily. The span value shall be between 60% and 80%. The optical surfaces

exposed to the effluent gases shall be cleaned prior to performing the zero and

span drift adjustments. The optical surfaces shall be cleaned when the cumulative

automatic zero compensation exceeds 4 percent opacity.

Minimum procedures must include an automated method for producing a simulated

zero opacity condition and an upscale opacity condition as specified in 40 CFR

60.13(d)(2).

Minn. R. 7017.1210, subp. 2

COMS Calibration Error Audit: due before end of each calendar half-year following

Permit Issuance. Conduct three point calibration error audits at least 3 months

apart but no greater than 8 months apart. Conduct audits in accordance with Minn.

R. 7017.1210, subp. 3.

Minn. R. 7017.1210, subp. 3

Attenuator Calibration: The Permittee shall have an independent testing company

conduct calibrations of each of the neutral density filters used in the calibration

error audit according to the procedure in 40 CFR Part 60, Appendix B, Section

7.1.3.1 within the time frame of opacity stability guaranteed by the attenuator

manufacturer. The manufacturer's guarantee of stability shall be available on-site

for inspection.

Minn. R. 7017.1210, subp. 4

COMS Calibration Error Audit Results Summary: due 30 days after end of each

calendar quarter in which the COMS calibration error audit was completed.

Minn. R. 7017.1220

Recordkeeping: The owner or operator must retain records of all COMS monitoring

data and support information for a period of five years from the date of the

monitoring sample, measurement or report. Records shall be kept at the source.

Minn. R. 7017.1130

PART 75 CEMS REQUIREMENTS hdr

Emissions Monitoring: The owner or operator shall measure opacity, SO2, NOx,

and CO2 emissions and flow rate for each affected unit in accordance with 40 CFR

Section 75.10.

40 CFR Section 75.10

Daily Calibration Error (CE) Test: Conduct daily CE testing on all CEMS required

by the Acid Rain Program, in accordance with 40 CFR pt. 75, Appendix B.

40 CFR pt. 75, Appendix B, section 2.1

Linearity and Leak Check Test (Acid Rain Program): due before end of each QA

operating quarter (as defined in Section 72.) in accordance with procedures in 40

CFR pt. 75, Appendix B, Sections 2.2.1 and 2.2.2, and Appendix A, Section 6.2.

Perform a leak check at least once during each QA operating quarter (calendar

quarter in which there are at least 168 unit operating hours) and no less than 30

days apart.

40 CFR pt. 75, Appendix B, sections 2.2.1 & 2.2.2;

Minn. R. 7017.1020
TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-14

Linearity Test Results Summary: due 30 days after end of each calendar quarter

following Linearity and Leak Check Test if performed.

Minn. R. 7017.1180, subp. 4

CEMS Relative Accuracy Test Audit (RATA): due before end of each calendar

half-year following CEM Certification Test, i.e., once every two successive QA

operating quarters (calendar quarter in which there are at least 168 unit operating

hours). Conduct a RATA on all CEMS required by the Acid Rain Program, in

accordance with 40 CFR pt. 75, Appendix B. Relative accuracy test audits may be

performed annually (i.e., once every four successive QA operating quarters, rather

than once every two successive QA operating quarters) if any of the conditions

listed in 40 CFR pt. 75, Appendix B, Section 2.3.1.2(a) through Section 2.3.1.2(i)

are met.

40 CFR pt. 75, Appendix B, section 2.3.1;

Minn. R. 7017.1020

Relative Accuracy Test Audit (RATA) Notification: due 30 days before CEMS

Relative Accuracy Test Audit (RATA)).

Minn. R. 7017.1180, subp. 2

Relative Accuracy Test Audit (RATA) Results Summary: due 30 days after end of

each calendar quarter in which the CEMS RATA was conducted.

Minn. R. 7017.1180, subp. 3

CEMS QA/QC: The owner or operator of an affected facility shall operate,

calibrate, and maintain each CEMS according to the QA/QC procedure in 40 CFR

pt. 75, Appendix B as amended.

40 CFR Section 75.21

Recordkeeping: The owner or operator must retain records of all CEMS monitoring

data and support information for a period of five years from the date of the

monitoring sample, measurement or report. Records shall be kept at the source.

40 CFR Section 75.50;

Minn. R 7017.1130
TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-15

Subject Item: EU 001 Boiler No. 1

Associated Items: CE 001 Electrostatic Precipitator - High Efficiency

GP 001 Three 745 MMBtu/hr coal-fired boilers

SV 001 Boiler 1 stack

What to do Why to do it

Refer To Subject Item SV 001 for NOx and SO2 CEMS Requirements and COMS

Requirements.

hdr

Total Particulate Matter: less than or equal to 0.3 lbs/million Btu heat input

(excluding condensible particulate matter).

Minn. R. 7007.0800, subp. 2; meets requirements of

Minn. R. 7011.0510, subp. 1

Opacity: less than or equal to 20 percent opacity except for one six-minute period

per hour of not more than 60 percent opacity.

Minn. R. 7011.0510, subp. 2

Sulfur Dioxide: less than or equal to 0.78 lbs/million Btu heat input using 3-hour

Average

Minn. R. 7009.0020 to not cause or contribute to a

violation of the SO2 ambient air standard in Minn. R.

7009.0080; meets the requirements of Minn. R.

7011.0510, subp. 1

Fuels allowed: bituminous coal, sub-bituminous coal, distillate fuel oil, used oil,

used oil sorbents, propane, and boiler cleaning agents.

Minn. R. 7007.0800, subp. 2

Performance Test: due before end of each 60 months starting 05/25/2005 to

measure particulate matter emissions. The tests shall be conducted at an interval

not to exceed 60 months between test dates.

Minn. R. 7017.2020, subp. 1

Boiler Alternative Operating Conditions for Performance Testing:

Alternative Operating Conditions during testing are defined as 90% to 100% of the

boiler's maximum normal (continuous) operating load or the maximum permitted

operating rate, whichever is lower. The basis for this number must be included in

the test plan. If testing is conducted at the alternative operating condition

established, an operating limit will not be established as a result of performance

testing.

In no case will the new operating rate limit be higher than allowed by an existing

permit condition.

Minn. R. 7017.2025, subps. 2(A) & 3(B)

Boiler Operating Conditions Not Meeting the Alternative Operating Conditions

During Performance Testing:

If performance testing is not conducted at or above the established alternative

operating condition, then the boiler operating rate will be limited on an 8-hour block

average based on the following:

1. If the results of the performance test are greater than 80% of any applicable

 emission limit for which emissions are measured, then boiler operation will

 be limited to the tested operating rate.

2. If results are less than or equal to 80% of all applicable emission limits for

 which emissions are measured, boiler operation will be limited to 110% of

 the tested operating rate.

In no case will the new operating rate limit be higher than allowed by an existing

permit condition.

Minn. R. 7017.2025, subp. 3(B)

STET (Short Term Emergency and Testing) Operating hours limit:

The boiler may operate up to 40 hours per year to demonstrate the Uniform Rating

of Generating Equipment (URGE) capacity and to meet emergency energy supply

needs. Documentation of all STET operation shall be maintained. The boiler must

meet emission limits during STET operation.

Minn. R. 7007.0800, subp. 2

STET Operation Definition that applies to Boilers that Meet or do Not Meet the

Alternative Operating Condition for Performance Testing:

If performance test results measure emissions at 80% or less of any applicable

emission limits for any tested pollutant, STET operation is defined as operation

beyond 110% of the average operating rate achieved during that performance test.

If performance test results measure emissions at greater than 80% any applicable

emission limit for any tested pollutant, STET operation is defined as operation

beyond 100% of the average operating rate achieved during that performance test.

In no case will STET operation be higher than allowed by an existing permit

condition.

Minn. R. 7007.0800, subp. 2
TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-16

ACID RAIN PROGRAM REQUIREMENTS hdr

Comply with the applicable Acid Rain emissions limitation for sulfur dioxide. 40 CFR Sections 72.9(c)(1)(ii) & 72.9(g)(4)

NOx Averaging Plan:

Beginning January 1, 2002, either:

Maintain an annual average NOx emission rate of 0.40 lbs/mmBtu and limit the

annual heat input to less than or equal to 5,600,000 mmBtu per year.

OR

Maintain a Btu-weighted annual average emission rate in lbs/mmBtu, averaged

over the units specified in the NOx averaging plan, that is less than or equal to the

Btu-weighted annual average emission rate averaged over the same units had they

each been operated during the same period of time in compliance with the

applicable emission limitations in 40 CFR Sections 76.5, 76.6, or 76.7. Units

covered in the plan are:

Plant Boiler ID#

Clay Boswell 1, 2, 3, 4

Syl Laskin 1, 2

Taconite Harbor 1, 2, 3

40 CFR Section 76.11

Recordkeeping: Keep on site at the source each of the following documents for a

period of 5 years from the date the document is created:

1. The certificate of representation;

2. All emissions monitoring information;

3. Copies of all reports, compliance certifications, and other submissions

 or records made under the Acid Rain Program;

4. Copies of all documents used to complete an acid rain permit application.

40 CFR Section 72.9(f)(l)

Apply for Acid Rain Program Permit reissuance: The designated representative

shall submit a complete Acid Rain permit application for each source with an

affected unit at least 6 months prior to the expiration of an existing Acid Rain Permit

in accordance with 40 CFR Section 72.30(c).

40 CFR Section 72.30(c)

Certify Acid Rain Program Submittals.

Each submission under the Acid Rain Program shall be submitted, signed, and

certified by the designated representative or the alternate designated

representative for all sources on behalf of which the submission is made in

accordance with 40 CFR Section 72.21.

40 CFR Section 72.21

Hold allowances as of the allowance transfer deadline, in the unit's compliance

subaccount not less than the total annual emissions of sulfur dioxide for the

previous calendar year. Takes effect for years beginning January 1, 2002.

Allowances shall be held in, deducted from, or transferred among Allowance

Tracking System accounts in accordance with the Acid Rain Program.

40 CFR Sections 72.9(c)(1)(i) & 72.9(g)(4)

The owner or operator shall measure opacity, and all SO2, NOx, and CO2

emissions for each affected unit in accordance with 40 CFR Section 75.10.

40 CFR Section 75.10
TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-17

Subject Item: EU 002 Boiler No. 2

Associated Items: CE 002 Electrostatic Precipitator - High Efficiency

CE 010 Selective Noncatalytic Reduction for NOX

CE 011 Dry Sorbent Injection

CE 012 Dry Sorbent Injection

CE 017 Ammonia Injection

CE 018 SO3 Injection

GP 001 Three 745 MMBtu/hr coal-fired boilers

SV 002 Boiler 2 stack

What to do Why to do it

Refer To Subject Item SV 002 for NOx and SO2 CEMS Requirements and COMS

Requirements.

EU 002 control equipment:

CE 010 is EU 002 furnace overfire air and SNCR with ammonia/urea/other reagent

 injection

CE 011 is EU 002 furnace alkaline/sodic/other reagent injection for SO2 control

CE 012 is EU 002 furnace sorbent/reagent injection for mercury control

CE 017 is ammonia injection upstream of CE 002 for particulate agglomeration

CE 018 is SO3 injection upstream of CE 002 to reduce particulate resistivity

hdr

LIMITS AND OPERATING REQUIREMENTS hdr

Nitrogen Oxides: less than or equal to 0.17 lbs/million Btu heat input using 365-day

Rolling Average effective 3/20/2009. Each daily value used in calculating the

365-day rolling average is determined by averaging all lb/mmBtu measurements

made by the SV 002 NOx CEMS during the calendar day. This is a state-only

requirement and is not enforceable under the Clean Air Act by citizens or the EPA

administrator.

Minn. R. 7007.0800, subp. 2

Sulfur Dioxide: less than or equal to 0.45 lbs/million Btu heat input using 365-day

Rolling Average effective 3/20/2009. Each daily value used in calculating the

365-day rolling average is determined by averaging all lb/mmBtu measurements

made by the SV 002 SO2 CEMS during the calendar day. This is a state-only

requirement and is not enforceable under the Clean Air Act by citizens or the EPA

administrator.

Minn. R. 7007.0800, subp. 2

Sulfur Dioxide: less than or equal to 0.78 lbs/million Btu heat input using 3-hour

Average

Minn. R. 7009.0020 to not cause or contribute to a

violation of the SO2 ambient air standard in Minn. R.

7009.0080; meets requirements of Minn. R.

7011.0510, subp. 1

Particulate Matter < 10 micron (PM10) and Front-half Particulate Matter (PM)

Emission Limits and Compliance Options:

The Permittee shall follow option 1 or option 2 described below for each pollutant.

If only one pollutant qualifies for option 1, the Permittee may implement option 1 for

the qualifying pollutant while following option 2 for the other pollutant.

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000; 40

CFR Section 52.21(r)(6)

Particulate Matter < 10 micron Compliance Options:

Option 1

1.a. Stack test to validate EU 002 PM10 emissions are less than or equal to the

 EU 002 0.120 lb/mmBtu PM10 emission factor, and

1.b. Monitor, record, and report EU 002 PM10 emissions as required by 40 CFR

 Section 52.21(r)(6); or

Option 2

2. Meet the EU 002 327 ton per year (12-month rolling sum basis) PM10 limit and

 all associated monitoring, recordkeeping, and reporting requirements in table A

 of this permit.

PM 10: If the most recent EU 002 PM10 emission factor testing results in a factor

greater than 0.120 lb/mmBtu, the Permittee shall follow option 2 for PM10.

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000; 40

CFR Section 52.21(r)(6)
TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-18

Front-half Particulate Matter Compliance Options:

Option 1

1.a. Stack test to validate EU 002 PM emissions are less than or equal to the

 EU 002 0.039 lb/mmBtu PM emission factor, and

1.b. Monitor, record, and report EU 002 PM emissions as required by 40 CFR

 Section 52.21(r)(6); or

Option 2

2. Meet the EU 002 106 ton per year (12-month rolling sum basis) PM limit and

 all associated monitoring, recordkeeping, and reporting requirements in table A

 of this permit.

Front-half PM: If the most recent EU 002 PM emission factor testing results in a

factor greater than 0.039 lb/mmBtu, the Permittee shall follow option 2 for PM.

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000; 40

CFR Section 52.21(r)(6)

Front-half Particulate Matter: less than or equal to 106 tons/year using 12-month

Rolling Sum .

This limit is in effect when operating under Option 2.

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000;

Total Particulate Matter: less than or equal to 0.3 lbs/million Btu heat input

(excluding condensible particulate matter).

Minn. R. 7007.0800, subp. 2; meets requirements of

Minn. R. 7011.0510, subp. 1

Opacity: less than or equal to 20 percent opacity except for one six-minute period

per hour of not more than 60 percent opacity.

Minn. R. 7011.0510, subp. 2

Fuels allowed: bituminous coal, sub-bituminous coal,distillate fuel oil, used oil,

Propane, used oil sorbents, and boiler cleaning agents.

Minn. R. 7007.0800, subp. 2

Control Equipment Operation During Startup and Shutdown: The Permittee is not

required to operate CE 010, CE 011, CE 012, CE 017, and CE 018 during startup

and shutdown as follows:

1. CE 010, CE 011, and CE 012 operation is not required if flue gas temperature

 in the injection zone is less than approximately 2000 degrees F;

2. CE 017 and CE 018 operation is not required during startup or shutdown when

 fuel oil is combusted.

Minn. R. 7007.0800, subp. 2

MONITORING AND RECORDKEEPING hdr

EU 002 Monthly Fuel Usage Monitoring and Recordkeeping: If the Permittee elects

or is required to meet option 2 PM and/or PM10 limits, by the last day of each

month, the Permittee shall calculate and record EU 002 monthly fuel usage of

sub-bituminous coal and bituminous coal.

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000;

Minn. R. 7007.0800, subps. 4 & 5

EU 002 PM Emissions Monitoring and Recordkeeping: If the Permittee elects or is

required to meet the option 2 PM limit, no later than 45 days after then end of each

month, the Permittee shall:

1. Calculate and record EU 002 monthly PM emissions as follows:

EU 002 PM = (FC * HC * EF)/2000

where:

EU 002 PM = monthly EU 002 PM emissions for each coal type (tons)

FC = EU 002 monthly fuel consumption for each coal type (tons)

HC = fuel heat content for each coal type (mmBtu/ton) determined by determined

by the most current ASTM method (presently ASTM D5865)

EF = current EU 002 PM emission factor for each coal type (lb/mmBtu)

2. Calculate and record the total EU 002 12-month rolling sum PM emissions for

 all coal combusted by summing the 12 most-recent monthly PM emissions

 calculations for each coal type.

Minn. R. 7007.0800, subps. 4 & 5
TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-19

EU 002 PM10 Emissions Monitoring and Recordkeeping: If the Permittee elects or

is required to meet the option 2 PM10 limit, no later than 45 days after then end of

each month, the Permittee shall:

1. Calculate and record EU 002 monthly PM10 emissions as follows:

EU 002 PM10 = (FC * HC * EF)/2000

where:

EU 002 PM10 = monthly EU 002 PM10 emissions for each coal type (tons)

FC = EU 002 monthly fuel consumption for each coal type (tons)

HC = fuel heat content for each coal type (mmBtu/ton) determined by determined

by the most current ASTM method (presently ASTM D5865)

EF = current EU 002 PM10 emission factor for each coal type (lb/mmBtu)

2. Calculate and record the total EU 002 12-month rolling sum PM10 emissions

 for all coal combusted by summing the 12 most-recent monthly PM10

 emissions calculations for each coal type.

Minn. R. 7007.0800, subps. 4 & 5

PM10 Periodic Monitoring: The PM CAM plan requirements shall fulfill periodic

monitoring for PM10 emissions, unless PM and PM10 performance testing

demonstrates no consistent relationship between PM and PM10 emission rates (for

example, on a lb/mmBtu basis and the same coal type, PM test results from an

agency-approved test are less than those for PM10, but in another

agency-approved performance test PM results exceed those for PM10).

Minn. R. 7007.0800, subps. 4(B) & 5(A)

COMPLIANCE ASSURANCE MONITORING hdr

Compliance Assurance Monitoring: Continuously monitor and record ESP total

secondary power, molten sulfur feed rate (surrogate for SO3 injection rate), and

ammonia flow rate (surrogate for ammonia injection rate) whenever EU 002 is

operating.

40 CFR Sections 64.6(c), 64.7(c), & 64.9(b)

Total Power Input: greater than or equal to 95 kilowatts using 3-hour Rolling

Average for ESP total power. This is the value measured during the most recent

PM performance test that demonstrated compliance. ESP total power is the sum of

the input power measured for each ESP electrical field. Field input power is

measured in kilowatts and is the product of the secondary voltage and secondary

current for each field. Secondary voltage and secondary current are measured

using digital metering onboard the power supplies for each electrical field. The

average must be recalculated once every hour to determine an average for the

previous three hours.

This limit applies unless a new limit is set pursuant to Minn. R. 7017.2025, subp. 3

based on the values recorded during the most recent MPCA-approved performance

test where compliance was demonstrated. The new limit shall be implemented

upon receipt of the Notice of Compliance letter granting preliminary approval. The

range is final upon issuance of a permit amendment incorporating the change.

40 CFR Section 64.6(c)

Ammonia: greater than or equal to 0 parts per million using 3-hour Rolling Average

measured at stack for Ammonia Injection. This is the value measured during the

most recent PM performance test that demonstrated compliance. Determined by

flow from the ammonia flowmeter amperage reading converted to parts per million

ammonia.

This limit applies unless a new limit is set pursuant to Minn. R. 7017.2025, subp. 3

based on the values recorded during the most recent MPCA-approved performance

test where compliance was demonstrated. The new limit shall be implemented

upon receipt of the Notice of Compliance letter granting preliminary approval. The

range is final upon issuance of a permit amendment incorporating the change.

40 CFR Section 64.6(c)

Liquid Flow Rate: greater than or equal to 0 parts per million using 3-hour Rolling

Average measured at stack of Molten Sulfur. This is the value measured during the

most recent PM performance test that demonstrated compliance. Determined by

sulfur pump speed cenveted to parts per million SO3.

This limit applies unless a new limit is set pursuant to Minn. R. 7017.2025, subp. 3

based on the values recorded during the most recent MPCA-approved performance

test where compliance was demonstrated. The new limit shall be implemented

upon receipt of the Notice of Compliance letter granting preliminary approval. The

range is final upon issuance of a permit amendment incorporating the change.

40 CFR Section 64.6(c)
TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-20

Excursions: An excursion is defined as any of the following:

1. ESP total power (3-hour rolling average) less than 95 kilowatts or value

determined during most recent PM performance test.

2. Molten sulfur feed rate (3-hour rolling average) measured as pump signal

 milliamps less than the value determined during most recent certified PM

performance test.

3. Ammonia flow rate (3-hour rolling average) less than the flow meter milliamps

 less than the value determined during most recent certified PM performance

test.

Respond to excursions as required by section 64.7(d) including inspection,

evaluation, and corrective action.

40 CFR Sections 64.6(c) & 64.7(d)

ESP Total Power CAM Performance Criteria:

1. ESP secondary voltage and current are measured using the instrumentation

provided by the ESP power supply manufacturer. These signals are brought into

the plant DCS/DAHS systems for recording and indication.

2. On an annual basis, confirm meter zero power readings when the ESP power

supplies are not operating.

3. Voltage and current are measured continuously and used to calculate the power

output every 15 minutes.

4. Hourly average power input is calculated and recorded based on the four

15-minute readings.

5. Hourly averages are used to determine the 3-hour rolling average total power

input.

40 CFR Section 64.6(c)

Molten Sulfur Feed Rate CAM Performance Criteria:

1. The molten sulfur pump Variable Frequency Drive (VFD) kilowatt output will be

measured using the instrumentation provided by the flue gas conditioning system

supplier.

2. In the event that the molten sulfur pump motor fails, the SO3 production controls

will alarm.

3. On an annual basis, confirm kilowatt feedback from the VFD reads 0 kilowatts

during standby mode for the flue gas conditioning system, or when EU 002 is not

operating.

4. The pump VFD kilowatt output feedback is measured continuously and brought

into the plant DCS/DAHS systems for recording and indication.

5. The averaging period is a 3-hour rolling average.

40 CFR Section 64.6(c)

Ammonia Flow Rate CAM Performance Criteria:

1. Measure the analog signal using the instrumentation and control system

provided by the flue gas conditioning system supplier.

2. If ammonia flow is interrupted, the NH3 production controls will alarm based on

NH3 flow failure.

3. On an annual basis, confirm ammonia flowmeter feedback reads zero flow

during standby mode for the flue gas conditioning system, or when EU 002 is not

operating.

4. The ammonia flowmeter feedback is measured continuously and brought into the

plant DCS/DAHS systems for recording and indication.

5. The averaging period is a 3-hour rolling average.

40 CFR Section 64.6(c)

CAM Excursions Reporting: The Permittee shall report all ESP total power, molten

sulfur injection, and ammonia injection excursions in the semiannual deviations

report required by this permit.

40 CFR Section 64.9(a)

Documentation For Need of Improved Monitoring: As required by Section 64.8(e),

promptly notify the agency and submit a permit application to address necessary

monitoring changes if the Permittee identifies noncompliance with the total

particulate matter limit (the 0.3 lb/mmBtu limit that meets Minn. R. 7011.0510,

subp. 1) .

40 CFR Section 64.7(e)

PARTICULATE MATTER CONTROL EQUIPMENT REQUIREMENTS (CE 002,

CE 017, AND CE 018)

hdr
TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-21

Ammonia Injection: Initial performance tests indicate ammonia injection is not

necessary to meet applicable EU 002 Option 1 or Option 2 PM or PM10

requirements. If the Permittee chooses to suspend ammonia injection or chooses

to operate it on a voluntary basis, all compliance assurance monitoring (CAM)

requirements pertaining to the ammonia injection system no longer apply. If future

tests indicate that ammonia injection is required to meet the Option 1 or Option 2

PM or PM10 requirements, then the CAM requirements apply.

Minn. R. 7007.0800, subp. 2

Notification Of Discontinuation of Use of Ammonia Injection: If the Permittee

discontinues use of the ammonia injection system, the Permittee shall submit

written notification of such to the agency, no later than 15 days after

discontinuation.

Minn. R. 7007.0800, subp. 2

Molten Sulfur Injection: Initial performance tests indicate molten sulfur injection is

not necessary to meet applicable EU 002 Option 1 or Option 2 PM or PM10

requirements. If the Permittee chooses to suspend molten sulfur injection or

chooses to operate it on a voluntary basis, all compliance assurance monitoring

(CAM) requirements pertaining to the molten sulfur injection system no longer

apply. If future tests indicate that molten sulfur injection is required to meet the

Option 1 or Option 2 PM or PM10 requirements, then the CAM requirements apply.

Minn. R. 7007.0800, subp. 2

Notification Of Discontinuation of Use of molten sulfur Injection: If the Permittee

discontinues use of the molten sulfur injection system, the Permittee shall submit

written notification of such to the agency, no later than 15 days after

discontinuation.

Minn. R. 7007.0800, subp. 2

MERCURY CONTROL EQUIPMENT (CE 012) REQUIREMENTS hdr

Mercury Control: Permittee is authorized to install and operate a furnace sorbent or

reagent injection system for the injection of mercury control sorbents or reagents.

The Permittee may use calcium bromide, activated carbon, or other mercury

reagents/sorbents provided a mercury emissions performance test is conducted no

later than 90 days after any new sorbent is installed and tuned, and the measured

mercury emissions rate is less than or equal to that measured by the most recent

MPCA-approved performance test.

If Permittee changes the mercury sorbent/reagent, the Permittee shall submit

written notification of such to the agency no later than 15 days after making the

change.

Minn. R. 7007.0800, subp. 2

Mercury additive feedrate: greater than or equal to 6 gallons/hour using 3-hour

Rolling Average . Calcium bromide with a density of 14.1 pounds per gallon. If a

supplemental reagent such as activated carbon is also used, then based on

subsequent stack performance testing, the calcium bromide injection rate may be

adjusted. If a different density reagent is procured, the injection rate may also be

adjusted in order to yield an equivalent Calcium bromide delivery rate as outlined

above.

Minn. R. 7007.0800, subp. 2

Mercury Reagent Injection: Immediately upon discovery of a drop of mercury

reagent injection rate below the value measured during the most recent mercury

performance test, initiate corrective actions to restore the mercury reagent injection

rate as soon as possible.

Minn. R. 7007.0800, subp. 2

Mercury Reagent Injection Monitoring: The Permittee shall install, maintain, and

operate at all times that EU 002 is operating, a system for monitoring and recording

the mercury reagent feed rate. Record the time periods, reasons, and corrective

actions taken for all EU 002 operating periods when mercury reagent flow rate is

below the required minimum.

Minn. R. 7007.0800, subp. 2

PERFORMANCE TESTING hdr

Performance Test: due before end of each 36 months starting 07/15/2008 to

measure mercury emissions.

The Permittee shall calculate mercury control efficiency based on results of each

performance test and uncontrolled mercury emissions determined by concurrent

fuel sampling, and submit the calculation in the report for each performance test.

Minn. R. 7017.2020, subp. 1

Performance Test: due before end of each 36 months starting 07/11/2008 to

measure particulate matter emissions. The tests shall be conducted at an interval

not to exceed 36 months between test dates.

Minn. R. 7017.2020, subp. 1

Performance Test: due before end of each 60 months starting 07/11/2008 to

measure PM10 emissions. The tests shall be conducted at an interval not to

exceed 60 months between test dates.

Minn. R. 7017.2020, subp. 1
TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-22

Boiler Alternative Operating Conditions for Performance Testing:

Alternative Operating Conditions during testing are defined as 90% to 100% of the

boiler's maximum normal (continuous) operating load or the maximum permitted

operating rate, whichever is lower. The basis for this number must be included in

the test plan. If testing is conducted at the alternative operating condition

established, an operating limit will not be established as a result of performance

testing.

In no case will the new operating rate limit be higher than allowed by an existing

permit condition.

Minn. R. 7017.2025, subps. 2(A) & 3(B)

Boiler Operating Conditions Not Meeting the Alternative Operating Conditions

During Performance Testing:

If performance testing is not conducted at or above the established alternative

operating condition, then the boiler operating rate will be limited on an 8-hour block

average based on the following:

1. If the results of the performance test are greater than 80% of any applicable

 emission limit for which emissions are measured, then boiler operation will

 be limited to the tested operating rate.

2. If results are less than or equal to 80% of all applicable emission limits for

 which emissions are measured, boiler operation will be limited to 110% of

 the tested operating rate.

In no case will the new operating rate limit be higher than allowed by an existing

permit condition.

Minn. R. 7017.2025, subp. 3(B)

STET (Short Term Emergency and Testing) Operating hours limit:

The boiler may operate up to 40 hours per year to demonstrate the Uniform Rating

of Generating Equipment (URGE) capacity and to meet emergency energy supply

needs. Documentation of all STET operation shall be maintained. The boiler must

meet emission limits during STET operation.

Minn. R. 7007.0800, subp. 2

STET Operation Definition that applies to Boilers that Meet or do Not Meet the

Alternative Operating Condition for Performance Testing:

If performance test results measure emissions at 80% or less of any applicable

emission limits for any tested pollutant, STET operation is defined as operation

beyond 110% of the average operating rate achieved during that performance test.

If performance test results measure emissions at greater than 80% any applicable

emission limit for any tested pollutant, STET operation is defined as operation

beyond 100% of the average operating rate achieved during that performance test.

In no case will STET operation be higher than allowed by an existing permit

condition.

Minn. R. 7007.0800, subp. 2

ACID RAIN PROGRAM REQUIREMENTS hdr

Comply with the applicable Acid Rain emissions limitation for sulfur dioxide. 40 CFR Sections 72.9(c)(1)(ii) & 72.9(g)(4)

NOx Averaging Plan:

Beginning January 1, 2002, either:

Maintain an annual average NOx emission rate of 0.40 lbs/mmBtu and limit the

annual heat input to less than or equal to 5,600,000 mmBtu per year.

OR

Maintain a Btu-weighted annual average emission rate in lbs/mmBtu, averaged

over the units specified in the NOx averaging plan, that is less than or equal to the

Btu-weighted annual average emission rate averaged over the same units had they

each been operated during the same period of time in compliance with the

applicable emission limitations in 40 CFR Sections 76.5, 76.6, or 76.7. Units

covered in the plan are:

Plant Boiler ID#

Clay Boswell 1, 2, 3, 4

Syl Laskin 1, 2

Taconite Harbor 1, 2, 3

40 CFR Section 76.11
TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-23

Recordkeeping: Keep on site at the source each of the following documents for a

period of 5 years from the date the document is created:

1. The certificate of representation;

2. All emissions monitoring information;

3. Copies of all reports, compliance certifications, and other submissions or

 records made under the Acid Rain Program;

4. Copies of all documents used to complete an acid rain permit application.

40 CFR Section 72.9(f)(l)

Apply for Acid Rain Program Permit reissuance: The designated representative

shall submit a complete Acid Rain permit application for each source with an

affected unit at least 6 months prior to the expiration of an existing Acid Rain Permit

in accordance with 40 CFR Section 72.30(c).

40 CFR Section 72.30(c)

Certify Acid Rain Program Submittals.

Each submission under the Acid Rain Program shall be submitted, signed, and

certified by the designated representative or the alternate designated

representative for all sources on behalf of which the submission is made in

accordance with 40 CFR Section 72.21.

40 CFR Section 72.21

Hold allowances as of the allowance transfer deadline, in the unit's compliance

subaccount not less than the total annual emissions of sulfur dioxide for the

previous calendar year. Takes effect for years beginning January 1, 2002.

Allowances shall be held in, deducted from, or transferred among Allowance

Tracking System accounts in accordance with the Acid Rain Program.

40 CFR Sections 72.9(c)(1)(i) & 72.9(g)(4)

The owner or operator shall measure opacity, and all SO2, NOx, and CO2

emissions for each affected unit in accordance with 40 CFR Section 75.10.

40 CFR Section 75.10
TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-24

Subject Item: EU 003 Boiler No. 3

Associated Items: CE 003 Electrostatic Precipitator - High Efficiency

GP 001 Three 745 MMBtu/hr coal-fired boilers

SV 003 Boiler 3 stack

What to do Why to do it

Refer To Subject Item SV 003 for NOx and SO2 CEMS Requirements and COMS

Requirements.

hdr

Total Particulate Matter: less than or equal to 0.3 lbs/million Btu heat input

(excluding condensible particulate matter).

Minn. R. 7007.0800, subp. 2; meets requirements of

Minn. R. 7011.0510, subp. 1

Opacity: less than or equal to 20 percent opacity except for one six-minute period

per hour of not more than 60 percent opacity.

Minn. R. 7011.0510, subp. 2;

Sulfur Dioxide: less than or equal to 0.78 lbs/million Btu heat input using 3-hour

Average

Minn. R. 7009.0020 to not cause or contribute to a

violation of the ambient SO2 standards in Minn. R.

7009.0080; meets the requirements of Minn. R.

7011.0510, subp. 1

Fuels allowed: bituminous coal, sub-bituminous coal, distillate fuel oil, used oil,

used oil sorbents, propane, and boiler cleaning agents.

Minn. R. 7007.0800, subp. 2

Performance Test: due before end of each 60 months starting 05/25/2005 to

measure particulate matter emissions. The tests shall be conducted at an interval

not to exceed 60 months between test dates.

Minn. R. 7017.2020, subp. 1

Boiler Alternative Operating Conditions for Performance Testing:

Alternative Operating Conditions during testing are defined as 90% to 100% of the

boiler's maximum normal (continuous) operating load or the maximum permitted

operating rate, whichever is lower. The basis for this number must be included in

the test plan. If testing is conducted at the alternative operating condition

established, an operating limit will not be established as a result of performance

testing.

In no case will the new operating rate limit be higher than allowed by an existing

permit condition.

Minn. R. 7017.2025, subps. 2(A) & 3(B)

Boiler Operating Conditions Not Meeting the Alternative Operating Conditions

During Performance Testing:

If performance testing is not conducted at or above the established alternative

operating condition, then the boiler operating rate will be limited on an 8-hour block

average based on the following:

1. If the results of the performance test are greater than 80% of any applicable

 emission limit for which emissions are measured, then boiler operation will

 be limited to the tested operating rate.

2. If results are less than or equal to 80% of all applicable emission limits for

 which emissions are measured, boiler operation will be limited to 110% of

 the tested operating rate.

In no case will the new operating rate limit be higher than allowed by an existing

permit condition.

Minn. R. 7017.2025, subp. 3(B)

STET (Short Term Emergency and Testing) Operating hours limit:

The boiler may operate up to 40 hours per year to demonstrate the Uniform Rating

of Generating Equipment (URGE) capacity and to meet emergency energy supply

needs. Documentation of all STET operation shall be maintained. The boiler must

meet emission limits during STET operation.

Minn. R. 7007.0800, subp. 2

STET Operation Definition that applies to Boilers that Meet or do Not Meet the

Alternative Operating Condition for Performance Testing:

If performance test results measure emissions at 80% or less of any applicable

emission limits for any tested pollutant, STET operation is defined as operation

beyond 110% of the average operating rate achieved during that performance test.

If performance test results measure emissions at greater than 80% any applicable

emission limit for any tested pollutant, STET operation is defined as operation

beyond 100% of the average operating rate achieved during that performance test.

In no case will STET operation be higher than allowed by an existing permit

condition.

Minn. R. 7007.0800, subp. 2
TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-25

ACID RAIN PROGRAM REQUIREMENTS hdr

Comply with the applicable Acid Rain emissions limitation for sulfur dioxide. 40 CFR Sections 72.9(c)(1)(ii) & 72.9(g)(4)

NOx Averaging Plan:

Beginning January 1, 2002, either:

Maintain an annual average NOx emission rate of 0.40 lbs/mmBtu and limit the

annual heat input to less than or equal to 5,600,000 mmBtu per year.

OR

Maintain a Btu-weighted annual average emission rate in lbs/mmBtu, averaged

over the units specified in the NOx averaging plan, that is less than or equal to the

Btu-weighted annual average emission rate averaged over the same units had they

each been operated during the same period of time in compliance with the

applicable emission limitations in 40 CFR Sections 76.5, 76.6, or 76.7. Units

covered in the plan are:

Plant Boiler ID#

Clay Boswell 1, 2, 3, 4

Syl Laskin 1, 2

Taconite Harbor 1, 2, 3

40 CFR Section 76.11

Recordkeeping: Keep on site at the source each of the following documents for a

period of 5 years from the date the document is created:

1. The certificate of representation;

2. All emissions monitoring information;

3. Copies of all reports, compliance certifications, and other submissions

 or records made under the Acid Rain Program;

4. Copies of all documents used to complete an acid rain permit application.

40 CFR Section 72.9(f)(l)

Apply for Acid Rain Program Permit reissuance: The designated representative

shall submit a complete Acid Rain permit application for each source with an

affected unit at least 6 months prior to the expiration of an existing Acid Rain Permit

in accordance with 40 CFR Section 72.30(c).

40 CFR Section 72.30(c)

Certify Acid Rain Program Submittals.

Each submission under the Acid Rain Program shall be submitted, signed, and

certified by the designated representative or the alternate designated

representative for all sources on behalf of which the submission is made in

accordance with 40 CFR Section 72.21.

40 CFR Section 72.21

Hold allowances as of the allowance transfer deadline, in the unit's compliance

subaccount not less than the total annual emissions of sulfur dioxide for the

previous calendar year. Takes effect for years beginning January 1, 2002.

Allowances shall be held in, deducted from, or transferred among Allowance

Tracking System accounts in accordance with the Acid Rain Program.

40 CFR Sections 72.9(c)(1)(i) & 72.9(g)(4)

The owner or operator shall measure opacity, and all SO2, NOx, and CO2

emissions for each affected unit in accordance with 40 CFR Section 75.10.

40 CFR Section 75.10
TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-26

Subject Item: EU 004 Heating Boiler - 34 mmBtu/hr

Associated Items: SV 004 Heating Boiler stack

What to do Why to do it

Heat Input: less than or equal to 29,784 million Btu/year using 12-month Rolling

Sum

Title I Condition: Limit to restrict annual capacity factor

to qualify as a limited use boiler under 40 CFR Section

63.7575

Total Particulate Matter: less than or equal to 0.6 lbs/million Btu heat input Minn. R. 7011.0510, subp. 1

Opacity: less than or equal to 20 percent opacity except that a maximum of 60

percent opacity shall be permissible for four minutes in any 60-minute period and

that a maximum of 40 percent opacity shall be permissible for four additional

minutes in any 60-minutes period.

Minn. R. 7011.0510, subp. 2

Fuel type limited to distillate fuel oil. Minn. R. 7007.0800, subp. 2

Heat Input Monitoring and Recordkeeping: By the last day of each month calculate

and record:

1. EU 004 monthly fuel usage and (convert to) monthly heat input for the

 previous calendar month;

2. EU 004 heat input for the previous 12-month period by summing the

 monthly heat inputs for the previous 12 months.

Title I Condition: Recordkeeping for annual capacity

factor to qualify as a limited use boiler under 40 CFR

Section 63.7575;

Minn. R. 7007.0800, subps. 4 & 5
TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-27

Subject Item: EU 005 Cold Start Generator

Associated Items: SV 005 Cold Start Generator stack

What to do Why to do it

Opacity: less than or equal to 20 percent opacity once operating temperatures have

been attained.

Minn. R. 7011.2300, subp. 1

Sulfur Dioxide: less than or equal to 0.5 lbs/million Btu heat input Minn. R. 7011.2300, subp. 2

Fuel type limited to distillate fuel oil. Minn. R. 7007.0800, subp. 2
TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-28

Subject Item: EU 006 Ash Collection Baghouse

Associated Items: CE 004 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 006 Ash Collection Baghouse stack

What to do Why to do it

Total Particulate Matter: less than or equal to 0.30 grains/dry standard cubic foot of

exhaust gas unless required to further reduce emissions to comply with the less

stringent limit of either Minn. R. 7011.0730 or Minn. R. 7011.0735.

Minn. R. 7011.0710, subp. 1(A)

Opacity: less than or equal to 20 percent opacity except for one six-minute period

per hour of not more than 60 percent opacity.

Minn. R. 7011.0710, subp. 1(B)

The Permittee shall operate and maintain CE 004 so that it achieves an overall

control efficiency for Total Particulate Matter: greater than or equal to 99 percent

control efficiency

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000;

Minn. R. 7007.0800, subps. 2 & 14

The Permittee shall operate and maintain CE 004 so that it achieves an overall

control efficiency for Particulate Matter < 10 micron: greater than or equal to 99

percent control efficiency

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000;

Minn. R. 7007.0800, subps. 2 & 14

The Permittee shall operate and maintain CE 004 at all times that any emission unit

controlled by the fabric filter is in operation.

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000;

Minn. R. 7007.0800, subps. 2 & 14

Visible Emissions: The Permittee shall check the stack/vent for CE 004 for any

visible emissions once each week of operation.

All observations shall be made during daylight hours.

Title I Condition: To avoid major modification under 40

CFR Section 52.21(b) and Minn. R. 7007.3000;

Minn. R. 7007.0800, subps. 4 & 5

Recordkeeping of Visible Emissions: The Permittee shall record the time and date

of each visible emission inspection and whether or not any visible emissions were

observed.

Title I Condition: To avoid classification as a major

source and modification under 40 CFR Section 52.21

and Minn. R. 7007.3000;

Minn. R. 7007.0800, subps. 4 & 5

Periodic Inspections: The Permittee shall inspect the fabric filter components once

per calendar quarter or as required by the manufacturer. The Permittee shall

maintain a written record of these inspections.

Minn. R. 7007.0800, subps. 4, 5, & 14

Corrective Actions: The Permittee shall take corrective action as soon as possible

if any of the following occur:

1. Visible emissions are observed;

2. During an inspection, the fabric filter or any of its components are found

 to need repair.

Corrective actions shall eliminate visible emissions, and/or include completion of

necessary repairs identified during the inspection, as applicable. Corrective actions

include, but are not limited to, those outlined in the O&M Plan for the fabric filter.

The Permittee shall keep a record of the type and date of any corrective action

taken for each filter.

Minn. R. 7007.0800, subps. 4, 5, & 14
TABLE A: LIMITS AND OTHER REQUIREMENTS 10/19/09

Minnesota Power - Tac Harbor Energy Ctr

03100001 - 008

Facility Name:

Permit Number:

A-29

Subject Item: EU 011 Crusher and Related Transfer Points

Associated Items: CE 019 Fabric Filter - Low Temperature, i.e., T<180 Degrees F

SV 011 Crusher Baghouse

What to do Why to do it

LIMITS hdr

Opacity: less than or equal to 20 percent opacity 40 CFR Section 60.252(c);

Minn. R. 7011.1105(G)

The Permittee shall operate and maintain CE 019 so that it achieves an overall

control efficiency for Particulate Matter < 10 micron: greater than or equal to 99

percent control efficiency

Minn. R. 7007.0800, subps. 2, 4, & 5

The Permittee shall operate and maintain CE 019 so that it achieves an overall

control efficiency for Total Particulate Matter: greater than or equal to 99 percent

control efficiency

Minn. R. 7007.0800, subps. 2, 4, & 5

MONITORING AND RECORDKEEPING hdr

The Permittee shall check the fabric filter stack for any visible emissions once each

day of operation during daylight hours.

Minn. R. 7007.0800, subps. 4 & 5

Recordkeeping of Visible Emissions: The Permittee shall record the time and date

of each visible emission inspection and whether or not any visible emissions were

observed.

Minn. R. 7007.0800, subps. 4 & 5

CE 019 shall operate all listed control equipment located at the stationary source

whenever operating the coal crusher and/or associated conveyers.

Minn. R. 7007.0800, subps. 4 & 5

Periodic Inspections: The Permittee shall inspect the fabric filter components once

per calendar quarter or as required by the manufacturer. The Permittee shall

maintain a written record of these inspections.

Minn. R. 7007.0800, subps. 4, 5, & 14

Corrective Actions: The Permittee shall take corrective action as soon as possible

if any of the following occur:

1. Visible emissions are observed;

2. During an inspection, the fabric filter or any of its components are found

 to need repair.

Corrective actions shall eliminate visible emissions, and/or include completion of

necessary repairs identified during the inspection, as applicable. Corrective actions

include, but are not limited to, those outlined in the O&M Plan for the fabric filter.

The Permittee shall keep a record of the type and date of any corrective action

taken for each filter.

Minn. R. 7007.0800, subps. 4, 5, & 14

Notification of any physical or operational change which increases emission rate:

due 60 days (or as soon as practical) before the change is commenced.

40 CFR Section 60.7(a)(4);

Minn. R. 7019.0100, subp. 1

TABLE B: SUBMITTALS

Facility Name: Minnesota Power - Tac Harbor Energy Ctr

Permit Number: 03100001 - 008

B-1 10/19/09

Each submittal must be postmarked or received by the date specified in the applicable Table. Those submittals required by parts

7007.0100 to 7007.1850 must be certified by a responsible official, defined in Minn. R. 7007.0100, subp. 21. Other submittals shall

be certified as appropriate if certification is required by an applicable rule or permit condition.

Send submittals that are required to be submitted to the U.S. EPA regional office to:

 Mr. George Czerniak

 Air and Radiation Branch

 EPA Region V

 77 West Jackson Boulevard

 Chicago, Illinois 60604

Table B lists most of the submittals required by this permit. Please note that some submittal requirements may appear in Table A

or, if applicable, within a compliance schedule located in Table C. Table B is divided into two sections in order to separately list

one-time only and recurrent submittal requirements.

Send submittals that are required by the Acid Rain Program to:

 U.S. Environmental Protection Agency

 Clean Air Markets Division

 1200 Pennsylvania Avenue NW (6204N)

 Washington, D.C. 20460

Send any application for a permit or permit amendment to:

 AQ Permit Technical Advisor

 Industrial Division

 Minnesota Pollution Control Agency

 520 Lafayette Road North

 St. Paul, Minnesota 55155-4194

Also, where required by an applicable rule or permit condition, send to the Permit Technical Advisor notices of:

- accumulated insignificant activities,

- installation of control equipment,

- replacement of an emissions unit, and

- changes that contravene a permit term.

Unless another person is identified in the applicable Table, send all other submittals to:

 AQ Compliance Tracking Coordinator

 Industrial Division

 Minnesota Pollution Control Agency

 520 Lafayette Road North

 St. Paul, Minnesota 55155-4194
TABLE B: ONE TIME SUBMITTALS OR NOTIFICATIONS

Facility Name: Minnesota Power - Tac Harbor Energy Ctr

Permit Number: 03100001 - 008

B-2 10/19/09

What to send When to send Portion of Facility Affected

Application for Permit Reissuance due 180 days before expiration of Existing

Permit

Total Facility

Submittal of Permit Application due 90 days after achieving normal operation

of combined calcium bromide and activated

carbon injection systems, conduct

performance test for EU 002 mercury

emissions. Within 90 days of performance test

completion, submit permit application. The

application shall contain the appropriate forms

for a major amendment to this permit to add

an EU 002 mercury emission limit and/or

control efficiency, mercury control monitoring

parameter ranges, and minimum parameter

values for the parameters as described in the

Mercury Control Requirements section of the

permit.

An extension was given due to the difficulties

with quantifing control perameters for proper

murcury removal.

Total Facility
TABLE B: RECURRENT SUBMITTALS

Facility Name: Minnesota Power - Tac Harbor Energy Ctr

Permit Number: 03100001 - 008

B-3 10/19/09

What to send When to send Portion of Facility Affected

Excess Emissions/Downtime Reports (EER's) due 30 days after end of each calendar

quarter starting 05/19/1997 (Submit

Deviations Reporting Form DRF-1 as

amended). The EER shall indicate all periods

of monitor bypass and all periods of

exceedances of the limit including

exceedances allowed by an applicable

standard, i.e. during startup, shutdown, and

malfunctions.

SV001

Excess Emissions/Downtime Reports (EER's) due 30 days after end of each calendar

quarter starting 05/19/1997 (Submit

Deviations Reporting Form DRF-1 as

amended). The EER shall indicate all periods

of monitor bypass and all periods of

exceedances of the limit including

exceedances allowed by an applicable

standard, i.e. during startup, shutdown, and

malfunctions.

SV002

Excess Emissions/Downtime Reports (EER's) due 30 days after end of each calendar

quarter starting 05/19/1997 (Submit

Deviations Reporting Form DRF-1 as

amended). The EER shall indicate all periods

of monitor bypass and all periods of

exceedances of the limit including

exceedances allowed by an applicable

standard, i.e. during startup, shutdown, and

malfunctions.

SV003

Semiannual Deviations Report due 30 days after end of each calendar

half-year starting 05/19/1997 . The first

semiannual report submitted by the Permittee

shall cover the calendar half-year in which the

permit is issued. The first report of each

calendar year covers January 1 - June 30.

The second report of each calendar year

covers July 1 - December 31. If no deviations

have occurred, the Permittee shall submit the

report stating no deviations.

Total Facility

Compliance Certification due 30 days after end of each calendar year

starting 05/19/1997 (for the previous calendar

year). Submit the certification on a form

approved by the Commissioner, both to the

Commissioner and to the US EPA regional

office in Chicago. This certification covers all

deviations experienced during the calendar

year.

Total Facility

APPENDIX MATERIAL 

Facility Name: Minnesota Power - Taconite Harbor Energy 

Permit Number: 03100001-008 

Phase II NOx Compliance Plan 

For more information, see instructions and refer to 40 CFR 76.9 

This submission is: New(Renewal) Revised 

Step 1 

Indicate plant name, 

State, and ORIS code 

from NADB, if applicable 

Taconite Harbor Energy Center 

Plant Name 

MN 

State 

10075 

ORIS Code 

Step 2 Identify each affected Group 1 and Group 2 boiler using the boiler ID# from 

NADB, if applicable. Indicate boiler type: “CB” for cell burner, “CY” for cyclone, 

“DBW” for dry botton wall-fired, “T” for tangetially fired, “V” for vertically fired, 

and “WB” for wet bottom. Indicate the compliance option selected for each unit 

ID# 1 ID# 2 ID# 3 ID# ID# ID# 

Type T Type T Type T Type Type Type 

(a) Standard annual average 

emission limitation of 0.50 

lb/mmBtu (for Phase I dry 

bottom wall-fired boilers)

 

(b) Standard annual average 

emission limitation of 0.45 

lb/mmBtu (for Phase I 

tangentially fired boilers)

 

(c) EPA-approved early 

election plan under 40 CFR 

76.8 through 12/31/07 (also 

indicate above emission limit 

specified in plan)

 

(d) Standard annual average 

emission limitation of 0.46 

lb/mmBtu (for Phase II dry 

bottom wall-fired boilers)

 

(e) Standard annual average 

emission limitation of 0.40 

lb/mmBtu (for Phase II 

tangentially fired boilers)

 

(f) Standard annual average 

emission limitation of 0.68 

lb/mmBtu (for cell burner 

boilers) 

 

X 
(g) Standard annual average 

emission limitation of 0.86 

lb/mmBtu (for cyclone 

boilers)

 

(h) Standard annual average 

emission limitation of 0.80 

lb/mmBtu (for vertically fired 

boilers)

 

(i) Standard annual average 

emission limitation of 0.84 

lb/mmBtu (for wet bottom 

boilers)

 

(j) NOx Averaging Plan 

(include NOx Averaging 

form)

X X X 

(k) Common stack pursuant 

to 40 CFR 75.17(a)(2)(i)(A) 

(check the standard 

emission 

limitation box above for 

most stringent limitation 

applicable to any unit 

utilizing stack

 

(l) Common stack pursuant 

to 40 CFR 75.17(a)(2)(i)(B) 

with NOx Averaging (check 

the NOx Averaging Plan box 

and include NOx Averaging 

form)

 

(m) EPA-approved common 

stack apportionment method 

pursuant to 40 CFR 75.17 

(a)(2)(i)(C), (a)(2)(iii)(B), or 

(b)(2)

 

(n) AEL (include Phase II 

AEL Demonstration Period, 

Final AEL Petition, or AEL 

Renewal form as 

appropriate)

 

(o) Petition for AEL 

demonstration period or 

final AEL under review by 

U.S. EPA or demonstration 

period ongoing

 

(p) Repowering extension 

plan approved or under 

review

 
Standard Requirements

General. This source is subject to the standard requirements in 40 CFR 72.9 (consistent with 40 CFR 76.8(e)(1)(i)). 

These requirements are listed in this source's Acid Rain Permit. 

Special Provisions for Early Election Units 

Nitrogen Oxides. A unit that is governed by an approved early election plan shall be subject to an emissions 

limitation for NO x as provided under 40 CFR 76.8(a)(2) except as provided under 40 CFR 76.8(e)(3)(iii). 

Liability. The owners and operators of a unit governed by an approved early election plan shall be liable for any 

violation of the plan or 40 CFR 76.8 at that unit. The owners and operators shall be liable, beginning January 1, 

2000, for fulfilling the obligations specified in 40 CFR Part 77. 

Termination. An approved early election plan shall be in effect only until the earlier of January 1, 2008 or January 

1 of the calendar year for which a termination of the plan takes effect. If the designated representative of the unit 

under an approved early election plan fails to demonstrate compliance with the applicable emissions limitation 

under 40 CFR 76.5 for any year during the period beginning January 1 of the first year the early election takes 

effect and ending December 31, 2007, the permitting authority will terminate the plan. The termination will take 

effect beginning January 1 of the year after the year for which there is a failure to demonstrate compliance, and the 

designated representative may not submit a new early election plan. The designated representative of the unit 

under an approved early election plan may terminate the plan any year prior to 2008 but may not submit a new 

early election plan. In order to terminate the plan, the designated representative must submit a notice under 40 

CFR 72.40(d) by January 1 of the year for which the termination is to take effect. If an early election plan is 

terminated any year prior to 2000, the unit shall meet, beginning January 1, 2000, the applicable emissions limitation for 

NO x for Phase II units with Group 1 boilers under 40 CFR 76.7. If an early election plan is terminated on or after 2000, 

the unit shall meet, beginning on the effective date of the termination, the applicable emissions limitation for NO x for Phase 

II units with Group 1 boilers under 40 CFR 76.7. 

Phase II NOx Averaging Plan 

For more information, see instructions and refer to 40 CFR 76.11 

This submission is: New (Renewal) Revised 

 (b) (c) 

 Alt. Annual 

 (a) Contemp. Heat 

 Emission Emission Input 

Step 1 Plant Name State ID# Limitation Limitation Limit 

Identify the units participating 

in this averaging plan by 

plant name, State, and boiler 

ID# from NADB. In column 

(a), fill in each unit’s 

applicable emission limitation 

from 40 CFR 76.5, 76.6, or 

76.7. In column (b), assign 

an alternative 

contemporaneous annual 

emissions limitation in 

lb/mmBtu to each unit. In 

column (c), assign an annual 

heat input limitation in 

mmBtu to each unit. 

Continue to page 3 if 

necessary. 

Boswell MN 1 0.46 0.45 3,500,000 

Boswell MN 2 0.46 0.45 3,500,000 

Boswell MN 3 0.40 0.39 19,000,000 

Boswell MN 4 0.40 0.35 33,000,000 

Laskin MN 1 0.40 0.50 4,600,000 

Laskin MN 2 0.40 0.50 4,600,000 

Taconite Harbor MN 1 0.40 0.45 5,600,000 

Taconite Harbor MN 2 0.40 0.45 5,600,000 

Taconite Harbor MN 3 0.40 0.45 5,600,000 

X 
Step 2 

Use the formula to enter the Btu-weighted annual emission rate averaged over the units if they are 

operated in accordance with the proposed averaging plan and the Btu-weighted annual averge 

emission rate for the same units if they are operated in compliance with 40 CFR 76.5, 76.6, or 76.7. 

The former must be less than or equal to the latter. 

Btu-weighted annual emission rate Btu-weighted annual average 

averaged over the units if they are emission rate for same units 

operated in accordance with the operated in compliance with 

proposed averaging plan 40 CFR 76.5, 76.6, or 76.7 

n n 

Σ (RLi x HIi) Σ [Rli x HIi] 

i=l i=l 

________________ < __________________ 

 n n 

 Σ HIi Σ HIi 

 i=l i=l 

Where, 

RLi = Alternative contemporaneous annual emission limitation 

 unit i, in lb/mmBtu, as specified in column (b) of Step 1: 

Rli = Applicable emission limitation for unit i, in lb/mmBtu, as 

 specified in column (a) of Step 1: 

HIi = Annual heat input for unit i, in mmBtu, as specified in 

 column (c) of Step 1: 

n = Number of units in the averaging plan 

This plan is effective for calendar year 2008 through calendar year 2012

unless notification to terminate the plan is given. 

Treat this plan as identical plans, each effective for one calendar year for the 

following calendar 

years ______, ______, ______, ______, and ______ unless notification to terminate one or more of these 

plans is given.

 

 0.40 

 

 

 

 0.40 

X 

 
Special Provisions 

Emission Limitations

Each affected unit in an approved averaging plan is in compliance with the Acid Rain emission limitation for NOx 

under the plan only if the following requirements are met: 

(i) For each unit, the unit's actual annual average emission rate for the calendar year, in lb/mmBtu, is less than or 

equal to its alternative contemporaneous annual emission limitation in the averaging plan, and 

(a) For each unit with an alternative contemporaneous emission limitation less stringent than the applicable emission 

limitation in 40 CFR 76.5, 76.6, or 76.7, the actual annual heat input for the calendar year does not exceed the annual 

heat input limit in the averaging plan, 

(b) For each unit with an alternative contemporaneous emission limitation more stringent than the applicable emission 

limitation in 40 CFR 76.5, 76.6, or 76.7, the actual annual heat input for the calendar year is not less than the annual 

heat input limit in the averaging plan, or 

(ii) If one or more of the units does not meet the requirements of (i), the designated representative shall demonstrate, in 

accordance with 40 CFR 76.11(d)(1)(ii)(A) and (B), that the actual Btu-weighted annual average emission rate for the 

units in the plan is less than or equal to the Btu-weighted annual average rate for the same units had they each been 

operated, during the same period of time, in compliance with the applicable emission limitations in 40 CFR 76.5, 76.6, 

or 76.7. 

(iii) If there is a successful group showing of compliance under 40 CFR 76.11(d)(1)(ii)(A) and (B) for a calendar year, 

then all units in the averaging plan shall be deemed to be in compliance for that year with their alternative 

contemporaneous emission limitations and annual heat input limits under (i). 

Liability

The owners and operators of a unit governed by an approved averaging plan shall be liable for any violation of the 

plan or this section at that unit or any other unit in the plan, including liability for fulfilling the obligations specified in 

part 77 of this chapter and sections 113 and 411 of the Act. 

Termination

The designated representative may submit a notification to terminate an approved averaging plan, in 

accordance with 40 CFR 72.40(d), no later than October 1 of the calendar year for which the plan is 

to be terminated. 

Acid Rain Permit Application 

For more information, see instructions and refer to 40 CFR 72.30 and 72.31 

This submission is New Revised 

Taconite Harbor Energy Center 

Plant Name

MN 

State

10075 

ORIS Code

 

a b c d 

Boiler ID# Unit Will Hold 

Allowances in 

Accordance with 40 

CFR 72.9(c)(1) 

New Units 

Commence 

Operation Date 

New Units 

Monitor Certification 

Deadline 

1 X Yes 

2 X Yes 

3 X Yes 

 Yes 

 Yes 

 Yes 

 Yes 

 Yes 

 Yes 

 Yes 

 Yes 

X 
Permit Requirements.

(1) The designated representative of each affected source and each affected unit at the source shall: 

 (i) Submit a complete Acid Rain permit application (including a compliance plan) under 40 CFR part 72 in accordance 

 with the deadlines specified in 40 CFR 72.30; and 

 (ii) Submit in a timely manner any supplemental information that the permitting authority determines is necessary in order 

 to review an Acid Rain permit application and issue or deny an Acid Rain permit; 

(2) The owners and operators of each affected source and each affected unit at the source shall: 

 (i) Operate the unit in compliance with a complete Acid Rain permit application or a superseding Acid Rain permit issued 

 by the permitting authority; and 

 (ii) Have an Acid Rain Permit. 

Monitoring Requirements.

(1) The owners and operators and, to the extent applicable, designated representative of each affected source and each affected

unit at the source shall comply with the monitoring requirements as provided in 40 CFR part 75. 

(2) The emissions measurements recorded and reported in accordance with 40 CFR part 75 shall be used to determine 

compliance by the unit with the Acid Rain emissions limitations and emissions reduction requirements for sulfur dioxide and 

nitrogen oxides under the Acid Rain Program. 

(3) The requirements of 40 CFR part 75 shall not affect the responsibility of the owners and operators to monitor 

emissions of other pollutants or other emissions characteristics at the unit under other applicable requirements of the Act and other 

provisions of the operating permit for the source. 

Sulfur Dioxide Requirements.

(1) The owners and operators of each source and each affected unit at the source shall: 

 (i) Hold allowances, as of the allowance transfer deadline, in the unit's compliance subaccount (after deductions under 40 

 CFR 73.34(c)), or in the compliance subaccount of another affected unit at the same source to the extent provided in 40 

 CFR 73.35(b)(3), not less than the total annual emissions of sulfur dioxide for the previous calendar year from the unit; and 

 (ii) Comply with the applicable Acid Rain emissions limitations for sulfur dioxide. 

(2) Each ton of sulfur dioxide emitted in excess of the Acid Rain emissions limitations for sulfur dioxide shall constitute a separate 

violation of the Act. 

(3) An affected unit shall be subject to the requirements under paragraph (1) of the sulfur dioxide requirements 

as follows: 

 (i) Starting January 1, 2000, an affected unit under 40 CFR 72.6(a)(2); or 

 (ii) Starting on the later of January 1, 2000 or the deadline for monitor certification under 40 CFR part 75, an affected unit

 under 40 CFR 72.6(a)(3). 

(4) Allowances shall be held in, deducted from, or transferred among Allowance Tracking System accounts in accordance with 

the Acid Rain Program. 

(5) An allowance shall not be deducted in order to comply with the requirements under paragraph (1)(i) of the sulfur dioxide 

requirements prior to the calendar year for which the allowance was allocated. 

(6) An allowance allocated by the Administrator under the Acid Rain Program is a limited authorization to emit sulfur dioxide in 

accordance with the Acid Rain Program. No provision of the Acid Rain Program, the Acid Rain permit application, the Acid Rain 

permit, or the written exemption under 40 CFR 72.7 and 72.8 and no provision of law shall be construed to limit the authority of 

the United States to terminate or limit such authorization. 

(7) An allowance allocated by the Administrator under the Acid Rain Program does not constitute a property 

right. 

Nitrogen Oxides Requirements. The owners and operators of the source and each affected unit at the source shall comply with 

the applicable Acid Rain emissions limitation for nitrogen oxides. 

Excess Emissions Requirements.

(1) The designated representative of an affected unit that has excess emissions in any calendar year shall submit a proposed 

offset plan, as required under 40 CFR part 77. 

(2) The owners and operators of an affected unit that has excess emissions in any calendar year shall: 

 (i) Pay without demand the penalty required, and pay upon demand the interest on that penalty, as required by 40 CFR 

 part 77; and 

 (ii) Comply with the terms of an approved offset plan, as required by 40 CFR part 77. 

Recordkeeping and Reporting Requirements.

(1) Unless otherwise provided, the owners and operators of the source and each affected unit at the source shall keep on site 

at the source each of the following documents for a period of 5 years from the date the document is created. This period may be

extended for cause, at any time prior to the end of 5 years, in writing by the Administrator or permitting authority: 

 (i) The certificate of representation for the designated representative for the source and each affected unit at the source 

 and all documents that demonstrate the truth of the statements in the certificate of representation, in accordance with 40 

 CFR 72.24; provided that the certificate and documents shall be retained on site at the source beyond such 5-year period 

 until such documents are superseded because of the submission of a new certificate of representation changing the 

 designated representative; 
 (ii) All emissions monitoring information, in accordance with 40 CFR part 75, provided that to the extent that 40 CFR part 

 75 provids for a 3-year period for recordkeeping, the 3-year period shall apply; 

 (iii) Copies of all reports, compliance certifications, and other submissions and all records made or required under the 

 Acid Rain Program; and, 

 (iv) Copies of all documents used to complete an Acid Rain permit application and any other submission under the Acid 

 Rain Program or to demonstrate compliance with the requirements of the Acid Rain Program. 

(2) The designated representative of an affected source and each affected unit at the source shall submit the reports and 

compliance certifications required under the Acid Rain Program, including those under 40 CFR part 72 subpart I and 40 CFR part 

75.

Liability.

(1) Any person who knowingly violates any requirement or prohibition of the Acid Rain Program, a complete Acid Rain permit 

application, an Acid Rain permit, or a written exemption under 40 CFR 72.7 or 72.8, including any requirement for the payment 

of any penalty owed to the United States, shall be subject to enforcement pursuant to section 113(c) 

of the Act. 

(2) Any person who knowingly makes a false, material statement in any record, submission, or report under the Acid Rain 

Program shall be subject to criminal enforcement pursuant to section 113(c) of the Act and 18 U.S.C. 1001. 

(3) No permit revision shall excuse any violation of the requirements of the Acid Rain Program that occurs prior to the date that 

the revision takes effect. 

(4) Each affected source and each affected unit shall meet the requirements of the Acid Rain Program. 

(5) Any provision of the Acid Rain Program that applies to an affected source (including a provision applicable to the designated 

representative of an affected source) shall also apply to the owners and operators of such source and of the affected units at the 

source. 

(6) Any provision of the Acid Rain Program that applies to an affected unit (including a provision applicable to the designated

representative of an affected unit) shall also apply to the owners and operators of such unit. Except as provided under 40 CFR 

72.44 (Phase II repowering extension plans) and 40 CFR 76.11 (NO x averaging plans), and except with regard to the requirements 

applicable to units with a common stack under 40 CFR part 75 (including 40 CFR 75.16, 75.17, and 75.18), the owners and 

operators and the designated representative of one affected unit shall not be liable for any violation by any other affected unit of 

which they are not owners or operators or the designated representative and that is located at a source of which they are not 

owners or operators or the designated representative. 

(7) Each violation of a provision of 40 CFR parts 72, 73, 74, 75, 76, 77, and 78 by an affected source or affected unit, or by an 

owner or operator or designated representative of such source or unit, shall be a separate violation of the 

Act. 

Effect on Other Authorities. No provision of the Acid Rain Program, an Acid Rain permit application, an Acid Rain permit, or a 

written exemption under 40 CFR 72.7 or 72.8 shall be construed as: 

(1) Except as expressly provided in title IV of the Act, exempting or excluding the owners and operators and, to the extent 

applicable, the designated representative of an affected source or affected unit from compliance with any other provision of the 

Act, including the provisions of title I of the Act relating to applicable National Ambient Air Quality Standards or State 

Implementation Plans; 

(2) Limiting the number of allowances a unit can hold; provided, that the number of allowances held by the unit shall not affect 

the source's obligation to comply with any other provisions of the Act; 

(3) Requiring a change of any kind in any State law regulating electric utility rates and charges, affecting any State law regarding 

such State regulation, or limiting such State regulation, including any prudence review requirements under such 

State law; 

(4) Modifying the Federal Power Act or affecting the authority of the Federal Energy Regulatory Commission under the Federal 

Power Act; or, 

(5) Interfering with or impairing any program for competitive bidding for power supply in a State in which such program is 

established. 

Technical Support Document, Permit Action Number: 03100001-008 

Page 1 of 5 

Date: 11/16/2009 

TECHNICAL SUPPORT DOCUMENT

For 

AIR EMISSION PERMIT NO. 03100001-008

This technical support document (TSD) is intended for all parties interested in the permit and to 

meet the requirements that have been set forth by the federal and state regulations (40 CFR § 

70.7(a)(5) and Minn. R. 7007.0850, subp. 1). The purpose of this document is to provide the 

legal and factual justification for each applicable requirement or policy decision considered in 

the preliminary determination to issue the permit. 

1. General Information

1.1 Applicant and Stationary Source Location:

Table 1. Applicant and Source Address 

Applicant/Address Stationary Source/Address 

(SIC Code: 4911) 

Minnesota Power 

30 West Superior St. 

Duluth, MN 55802

Taconite Harbor Energy Center 

8124 W Highway 61 

Schroeder 

Cook County 

Contact: Krogh, Brandon 

Phone: 218-723-3954

1.2 Facility Description

Minnesota Power’s Taconite Harbor Energy Center consists of three 745 MMBtu coal-fired units located in 

Schroeder, MN. The units have tangentially fired boilers that are permitted to burn both bituminous and 

sub-bituminous coals. Coal for the boilers is stored in an outdoor storage pile. The plant currently uses 

Montana Powder River Basin (PRB) sub-bituminous coal. 

1.3 Description of the Activities Allowed by this Permit Action

No physical changes will occur as part of this permit amendment. The permit amendment is 

primarily a revision to the State-Only (Non Title-I) emission limits of SO2 and NOx for EU002. 

In 2006, Minnesota Power installed Mobotec’s multi pollution control technologies as a pilot test 

project on Taconite Harbor Unit 2 boiler to reduce SO2, NOx, and Mercury. There was a 

possibility of a significant increase in PM and PM10 emissions due to the injection of lime based 

alkali into the boiler for SO2 control. There were various permit conditions put in the permit to 

avoid a significant increase of PM and PM10 under PSD. This permit amendment revises the 

state-only emissions limits due to uncertainties surrounding the control devices and technologies 

involved. It has proven necessary to operate the control system at a reduced hydrate injection 

rate in order to reliably meet the PM and PM10 limits. These reduced injection rates has caused 

the facility to be unable to achieve the level of SO2 expected by the pilot project. Likewise, the 
Technical Support Document, Permit Action Number: 03100001-008 

Page 2 of 5 

Date: 11/16/2009 

actual efficiency of the NOx reduction system is slightly less then anticipated. The revised 

emissions limits are 0.45 lbs/MMBtu SO2 and 0.17 lbs/MMBtu NOx. 

This permit amendment allows the facility to discontinue use of molten sulfur ejection as an ESP 

conditioning agent. Molten sulfur has been shown to have an inverse relationship with mercury 

removal. Stack tests have also shown that the facility can meet particulate limits without the use 

of SO3 injection. 

This permit amendment gives an extension for the submittal of the Mercury Removal Control 

Plan. Due to ongoing issues with the mercury capture reagent and interactions between other 

portions of the control systems, the facility requires an extension. This time will be used to tune 

and retest the control equipment. This extension has been reviewed and approved by Anne 

Jackson. 

This permit amendment removes requirement and citations that no longer apply. On February 8, 

2008, CAMR was vacated by the U.S. Court of appeals for the D.C. Circuit. 

This Permit also rolls in two Reopenings and an administrative amendment. 

1.4. Facility Emissions:

Table 2. Title I Emissions Increase Summary 

Pollutant 

Emissions 

Increase 

from the 

Modification

(tpy) 

PSD/112(g) 

Significant 

Thresholds 

for major 

sources 

(tpy)

NSR/ 

112(g) 

Review 

Required?

(Yes/No) 

PM 23.5 25 No 

PM10 12.1 15 No 

PM2.5 NA 10 No 

NOx -589 40 No 

SO2 -646 40 No 

CO 0 100 No 

Ozone (VOC) 0 40 No 

Lead 0 0.6 No 

Table 3. Facility Classification 

Classification Major/Affected Source Synthetic Minor Minor 

PSD PM, PM10, SOx, NOx, CO VOC 

Part 70 Permit Program PM10, SOx, NOx, CO VOC 

Part 63 NESHAP Single & Total HAPs 
Technical Support Document, Permit Action Number: 03100001-008 

Page 3 of 5 

Date: 11/16/2009 

2. Regulatory and/or Statutory Basis

New Source Review

The facility is an existing major source under New Source Review regulations. Table 2 is the 

summary of the revised Past-Actual to Future-Projected analysis. 

Part 70 Permit Program

The facility is a major source under the Part 70 permit program. 

New Source Performance Standards (NSPS)

The facility is subject to 40 CFR Part 60 Subpart Y Standard of Performance for Coal Preparation Plants. 

National Emission Standards for Hazardous Air Pollutants (NESHAP)

The facility is an existing major source of HAPs but this permit action does not change HAP emissions 

nor does it trigger a NESHAP standard. 

Compliance Assurance Monitoring (CAM)

CAM does not apply to the modification allowed in this permit amendment. 

3. Technical Information

New Source Review Calculations

Attachment 1 to this TSD contains a spreadsheet detailing the Title-I emissions calculations. 

There was sufficient data to determine the baseline actual emissions as defined at 

§52.21(b)(48)(i). The Permitee has two options for demonstrating the PM and PM10 emission 

increases are not significant under §52.21. Two options are available because the first option has 

reduced recordkeeping compared to the second option. PM and PM10 emission factor 

performance tests are required regardless of the option selected. 

Option 1 requires the Permitee to conduct the monitoring, recordkeeping and reporting 

requirements described at § 52.21(r)(6), if the PM and PM10 performance tests demonstrate that 

PM and PM10 emissions do not exceed the Title I 0.039 lb/mmBtu and 0.120 lb/mmBtu emission 

factors in the permit for PM and PM10, respectively. The Title I emission factors are based on 

guarantees by the contractor that has converted the ESP from hot-side to cold-side. 

If the Permittee can demonstrate that the PM and PM10 do not exceed these emission factors, the 

Permittee will not be subject to a 12-month rolling sum limit necessary to avoid significant 

emissions increases for PM and PM10. Instead, the Permittee will be subject to the annual 

emissions monitoring requirements at § 52.21(r)(6)(c)(iii) for a ten year period, and annual 

reporting (due within 60 days after the end of the calendar year) of the unit’s annual emissions 

for the previous calendar year as required by § 52.21(r)(6)(c)(iv). 

Option 2 applies if the Permittee can not demonstrate that the PM and PM10 emission factors do 

not exceed 0.039 lb/mmBtu and 0.120 lb/mmBtu for PM and PM10, respectively, or if the 

Permittee desires to be subject to the 12-month rolling sum limit regardless. The factors are 

based on guarantees from the control equipment vender the With this option, the Permittee will 
Technical Support Document, Permit Action Number: 03100001-008 

Page 4 of 5 

Date: 11/16/2009 

be subject to Title I 106 tpy and 327 tpy (12-month rolling sum basis) PM and PM10 limits, 

respectively, to restrict the emissions increase from the modification to less than the 25 tpy and 

15 tpy significant levels for PM and PM10, respectively. In addition, the Permittee will be 

subject to on-going monitoring, recordkeeping, and reporting requirements. 

If the Permittee is only able to meet option 1 requirements for one pollutant, the Permittee may 

follow option 1 for that pollutant while following option 2 for the other pollutant. 

The Permittee initially proposed a permit condition stating the Permittee may conduct a PSD 

analysis if it could not meet the option 1 PM and/or PM10 emissions factor requirement(s) to 

avoid concerns about potential sham permitting if the post-modification future actual annual PM 

and/or PM10 increase exceeds the PSD significant level(s). However, based on discussions with 

EPA Region V staff in St. Paul on May 18, 2006, EPA indicated sham permitting would not be 

an issue if the future PM and/or PM10 emissions increase is significant (providing the facility 

post-modification PM and/or PM10 emissions increase doesn’t exceed the significant level until 

the Permittee obtains a PSD major modification permit authorizing the increase). This is 

because the Permittee has attempted to the best of its ability to accurately determine future actual 

emissions, the non-major permit amendment limits the increases to less than significant levels, 

and there is inherent uncertainty in the PM and PM10 emission changes that will occur when 

retrofitting old boilers with new emissions control technology. 

3.1 Emissions Increase Analysis

Attachment 1 to this TSD contains the Title I net emissions increase calculations for this 

modification. This demonstrates that this modification is not a major modification for PSD. 

Attachment 1 contains the non-Title I calculations for this modification which demonstrate that 

the modification is a major amendment under Minn. R. 7007.1500. 

3.2 Periodic Monitoring

This permit amendment does not change any monitoring in the permit. In accordance with the 

Clean Air Act, it is the responsibility of the owner or operator of a facility to have sufficient 

knowledge of the facility to certify that the facility is in compliance with all applicable 

requirements. 

3.3 Permit Organization

In general, the permit meets the MPCA Delta Guidance for ordering and grouping of 

requirements. One area where this permit deviates slightly from Delta guidance is in the use of 

appendices. While appendices are fully enforceable parts of the permit, in general, any 

requirement that the MPCA thinks should be tracked (e.g., limits, submittals, etc.), should be in 

Table A or B. The main reason is that the appendices are word processing sections and are not 

part of the tracking system. Violation of the appendices can be enforced, but the computer 

system will not automatically generate the necessary enforcement notices or documents. Staff 

must generate these. 

3.5 Comments Received

Public Notice Period: August 21, 2009 - September 21, 2009 
Technical Support Document, Permit Action Number: 03100001-008 

Page 5 of 5 

Date: 11/16/2009 

EPA 45-day Review Period: August 21, 2009 – October 6, 2009 

Comments were not received from the public during the public notice period. 

4. Conclusion

Based on the information provided by Minnesota Power, the MPCA has reasonable assurance 

that the proposed operation of the emission facility, as described in the Air Emission Permit No. 

03100001-008 and this TSD, will not cause or contribute to a violation of applicable federal 

regulations and Minnesota Rules. 

Staff Members on Permit Team: Benjamin Klismith (permit writer/engineer) 

Steve Palzkill (enforcement) 

Andy Place (stack testing) 

Chris Buntjer (peer reviewer) 

AQ File No. 48A; DQ 2243, 2471, 2280 

Attachments: 1. Emissions Increase Calculation Spreadsheets 

2. Facility Description and CD-01 Forms 

OMB 2060-0631 Part I Question 14a

Minnesota Power Taconite Harbor Energy Center (10075)Materials listed in the permit

Taconite Harbor "Other" Material Permitted to burn Actually burn Quantity / year

Used oil NA No - Facilty-wide 

Used oil sorbents NA Yes 1,369 gal Facilty-wide 

Propane NA Yes 396 gal Facilty-wide 

Boiler cleaning agents NA No -

NA=No limit listed specifically in permit

Unit 1, Unit 2, and 

Unit 3

If "other" was checked in questions 10 or 11 above indicating that any non-fossil fuel or other material (including, but not limited 

plastics, treated wood, rubber belting or gaskets, whole tires, tire-derived fuel, boiler cleaning solutions, animal wastes, etc.) is utilized or permitted to be used, please indicate below what materials are combusted in the boiler and in what quantities (specifthis quantity is on a weight percentage or heat [Btu] basis). Also indicate (yes/no) whether you are permitted to burn non-fossil other material(s) even if you do not actually burn them. 
OMB 2060-0631 Part I, Question 15: Identification (or designation) of all coal- and oil-fired steam generating units (boilers) (as defined by Clean Air Act section 112(2)(8)) located at 

Minnesota Power Taconite Harbor Energy Center (10075)

Facility Name

Subpart EIA Plant CodeQ 15.01 Boiler ID Unit 1 Unit 2 Unit 3Q 15.02 Original design fuel (i.e. coal rank or type of oil) Midwest bituminous2 Midwest bituminous2 Midwest bituminous2Q 15.03 Design heat input (mmBtu/hr)1 762 762 756

Q 15.04 Present maximum heat input, (mmBtu/hr)3 847 913 908Q 15.05 MWe gross capacity summer 83 79.2 80Q 15.06 MWe Net capacity summer 78 74 76Q 15.07 Original design gross efficiency (%, HHV) 88.9 (12,535btu/lb) 88.9 (12,535btu/lb) 88.9 (12,535btu/lb)Q 15.08 Present operating gross efficiency (%, HHV)4 NA NA NA

Q 15.09 Design steam pressure (psig)1 1450 1450 1450

Q 15.10 Operating steam pressure (psig) 1450 1450 1450Q 15.11 Design steam temperature (°F)1 1000 1000 1000Q 15.12 Operating steam temperature (°F) 1000 1000 1000Q 15.13 Design steam reheat temperature (°F)1 1000 1000 1000Q 15.14 Operating steam reheat temperature (°F) 1000 1000 1000Q 15.15 FuelQ 15.16 Hours/year operated 7794.44 7402.85 8081.53Q 15.17 Average annual capacity factor for the past 3 years 71.98 70.7 75.56Q 15.18 Applicable NSPSQ 15.19 Estimated year of retirement Minnesota Power has no scheduled or planned retirement dates for any of our units

1Original design values based on boiler acquisition contracts and/or heat balance drawings. Design heat input value does not represent maximum capacity at the time of unit commis2Units were built for midwest bituminous but currently subbitminous PRB coal is being burned3Current heat input data from Title V permit application does not represent maximum heat input capacity.4We do not measure or calculate boiler efficiency on the units at this facility. 

TACONITE HARBOR

10075

 40 CFR Part 60 Subpart Y 

>99% coal, <1%other
OMB 2060-0631 Part I, Question 16: Emission Control Technology

Minnesota Power Taconite Harbor Energy Center (10075)Designate the order of the emission controls -- 1 for first control following the boiler, 2 for second control following the boiler, etc.

Plant ID Boiler ID Type NOx Control In-service Date SO2 Control In-service Date PM Control In-service Date 

Tac Harbor 1 Tangentially-fired 1 - ROFA / SNCR 2008 2 - Boiler alkali injection 2008 3 - ESP conversion hot-side to cold-side 2008 

10075 2 Tangentially-fired 1 - ROFA / SNCR 2007 2 - Boiler alkali injection 2007 4 - ESP conversion hot-side to cold-side 2007 

3 Tangentially-fired Good combustion practices - Low sulfur coal - 1 - Hot side ESP 1974 
OMB 2060-0631 Part I Question 22: Guaranteed Emission Rate

Minnesota Power Taconite Harbor Energy Center (10075)

PM PM10 PM2.5 SO2 HCl and/or HF HCN Metal HAP Hg CO 

1 0.03 lb/mmBtu 0.24 lb/mmBtu

2 0.03 lb/mmBtu 0.24 lb/mmBtu

3

Mostrecent guaranteed emission rate for each pollutant for which there is a permitted emission lim

Taconite 

Harbor 

(10075)

Plant ID Boiler ID
OMB 2060-063 Part II Questions 2-3

Minnesota Power Taconite Harbor Energy Center (10075)Coal Shipments - Taconite Harbor Energy Center

Train ID Tons Boiler ID# State County Coal Seam

Fuel Ship 

Method Sulfur Ash Btu/Lb Mercury Chlorine F

DKMSUM301 14,821.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.410 4.520 9,175 N/A N/A DKMSUM302 13,255.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.420 4.680 9,226 N/A N/A DKMSUM303 14,813.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.380 4.570 9,315 N/A N/A DKMSUM304 14,785.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.390 4.790 9,278 N/A N/A DKMSUM305 14,815.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.400 4.660 9,353 N/A N/A DKMSUM306 14,823.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.440 4.660 9,390 N/A N/A DKMSUM307 14,825.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.320 3.590 9,356 N/A N/A DKMSUM308 14,875.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.290 3.930 9,251 N/A N/A DKMSUM309 13,858.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.440 4.420 9,422 N/A N/A DKMSUM310 14,823.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.420 4.180 9,507 N/A N/A DKMSUM311 13,866.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.400 4.140 9,454 N/A N/A DKMSUM312 13,860.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.430 4.290 9,562 N/A N/A DKMSUM313 14,920.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.400 3.950 9,611 N/A N/A DKMSUM314 13,475.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.400 4.070 9,487 N/A N/A DKMSUM315 14,792.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.390 4.240 9,404 N/A N/A DKMSUM316 14,185.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.390 3.890 9,602 N/A N/A DKMSUM317 14,099.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.430 4.060 9,612 N/A N/A DKMSUM318 14,196.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.380 3.850 9,614 N/A N/A DKMSUM319 13,858.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.260 3.210 9,556 N/A N/A DKMSUM320 13,860.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.310 3.510 9,421 N/A N/A DKMSUM321 14,701.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.380 4.280 9,561 N/A N/A DKMSUM322 14,825.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.340 4.190 9,526 N/A N/A DKMSUM323 14,858.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.270 3.750 9,417 N/A N/A DKMSUM324 14,820.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.330 3.860 9,492 N/A N/A DKMSUM325 14,813.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.310 3.930 9,338 N/A N/A DKMSUM326 14,839.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.290 3.480 9,303 N/A N/A DKMSUM327 14,572.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.360 4.620 9,332 N/A N/A DKMSUM328 14,365.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.360 4.020 9,631 N/A N/A DKMSUM329 14,840.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.320 4.530 9,373 N/A N/A DKMSUM330 14,827.000 1,2,3 MT Big Horn Dietz 1 and Dietz 2 RR 0.380 4.420 9,431 N/A N/A SCMSUM601 13,433.925 1,2,3 MT Big Horn Anderson Dietz RR 0.310 4.400 9,575 N/A N/A SCMSUM602 13,356.450 1,2,3 MT Big Horn Anderson Dietz RR 0.290 5.570 9,290 N/A N/A SCMSUM603 13,904.350 1,2,3 MT Big Horn Anderson Dietz RR 0.300 3.860 9,327 N/A N/A SCMSUM605 13,991.600 1,2,3 MT Big Horn Anderson Dietz RR 0.380 4.830 9,348 N/A N/A SCMSUM606 14,860.275 1,2,3 MT Big Horn Anderson Dietz RR 0.330 4.000 9,332 N/A N/A SCMSUM607 15,108.550 1,2,3 MT Big Horn Anderson Dietz RR 0.330 4.480 9,380 N/A N/A SCMSUM608 14,975.125 1,2,3 MT Big Horn Anderson Dietz RR 0.270 4.510 9,440 N/A N/A BTMSUM101 14,765.150 1,2,3 WY Campbell N/A RR 0.280 4.710 8,974 N/A N/A 

N:\Projects\0210426-EPA_SPPD_(Opt3)\0210426.003.001-EGU_MACT\Data_and_Tools\2010_ICR_Collected_Data\Original\Archive\Allete_Har

Parts I & II.xls
BTMSUM103 14,347.000 1,2,3 WY Campbell N/A RR 0.260 5.040 8,787 N/A N/A 

BTMSUM104 14,274.050 1,2,3 WY Campbell N/A RR 0.320 5.960 8,692 N/A N/A BTMSUM102 13,937.350 1,2,3 WY Campbell N/A RR 0.230 5.160 8,803 N/A N/A BTMSUM105 14,660.450 1,2,3 WY Campbell N/A RR 0.300 4.780 8,959 N/A N/A BTMSUM106 14,888.950 1,2,3 WY Campbell N/A RR 0.250 4.410 8,961 N/A N/A BTMSUM107 14,062.400 1,2,3 WY Campbell N/A RR 0.230 4.420 8,908 N/A N/A BTMSUM108 14,839.300 1,2,3 WY Campbell N/A RR 0.250 4.620 8,866 N/A N/A WTMSUM101 14,579.700 1,2,3 WY Campbell N/A RR 0.300 4.880 8,777 N/A N/A WTMSUM102 14,952.500 1,2,3 WY Campbell N/A RR 0.300 5.380 8,873 N/A N/A BTMSUM109 14,951.500 1,2,3 WY Campbell N/A RR 0.280 4.790 8,910 N/A N/A BTMSUM110 14,955.950 1,2,3 WY Campbell N/A RR 0.250 5.420 8,837 N/A N/A 

Oil Shipments - Taconite Harbor Energy Center

OMB 2060-063 Part II Question 3

ID Gallons Boiler ID# State County Coal Seam

Fuel Ship 

Method Sulfur Ash Btu/Lb Mercury Chlorine F

COMO333621 7,514.00 1,2,3 MN N/A N/A TR 0.200 0.100 ###### N/A N/A NCOMO106886 7,502.00 1,2,3 MN N/A N/A TR 0.200 0.100 ###### N/A N/A NCOMO106880 7,503.00 1,2,3 MN N/A N/A TR 0.200 0.100 ###### N/A N/A NCOMO107530 7,500.00 1,2,3 MN N/A N/A TR 0.200 0.100 ###### N/A N/A NCOMO107483 7,500.00 1,2,3 MN N/A N/A TR 0.200 0.100 ###### N/A N/A NCOMO337873 7,509.00 1,2,3 MN N/A N/A TR 0.200 0.100 ###### N/A N/A NCOMO337875 5,862.00 1,2,3 MN N/A N/A TR 0.200 0.100 ###### N/A N/A NCOMO338246 7,506.00 1,2,3 MN N/A N/A TR 0.200 0.100 ###### N/A N/A NCOMO114086 7,505.00 1,2,3 MN N/A N/A TR 0.200 0.100 ###### N/A N/A NCOMO114507 7,500.00 1,2,3 MN N/A N/A TR 0.200 0.100 ###### N/A N/A NCOMO60171 7,500.00 1,2,3 MN N/A N/A TR 0.200 0.100 ###### N/A N/A NCOMO63745 7,514.00 1,2,3 MN N/A N/A TR 0.200 0.100 ###### N/A N/A NCOMO343654 7,506.00 1,2,3 MN N/A N/A TR 0.200 0.100 ###### N/A N/A NCOMO343979 7,513.00 1,2,3 MN N/A N/A TR 0.200 0.100 ###### N/A N/A NCOMO345852 7,500.00 1,2,3 MN N/A N/A TR 0.200 0.100 ###### N/A N/A NCOMO346400 7,507.00 1,2,3 MN N/A N/A TR 0.200 0.100 ###### N/A N/A NCOMO347019 7,513.00 1,2,3 MN N/A N/A TR 0.200 0.100 ###### N/A N/A NCOMO347353 7,500.00 1,2,3 MN N/A N/A TR 0.200 0.100 ###### N/A N/A NCOMO347399 7,502.00 1,2,3 MN N/A N/A TR 0.200 0.100 ###### N/A N/A NCOMO347708 7,513.00 1,2,3 MN N/A N/A TR 0.200 0.100 ###### N/A N/A NCOMO349056 7,500.00 1,2,3 MN N/A N/A TR 0.200 0.100 ###### N/A N/A N

Fuel Source

N:\Projects\0210426-EPA_SPPD_(Opt3)\0210426.003.001-EGU_MACT\Data_and_Tools\2010_ICR_Collected_Data\Original\Archive\Allete_Har

Parts I & II.xls
OMB 2060-0631 Part II, Question 8a, 8b, 8f

Minnesota Power Taconite Harbor Energy Center (10075)Boiler ID(as listed in Part I question 15)

Question 8a Emission test report, parametric monitoring data, or other data or monitoring

Question 8bDate of testing

Question 8bType of testing

Question 8bConstituents

Question 8fDid the unit's control configuration differ for that shown in Part I, questions 16 at the time of the test? Boiler ID

Boiler 1 Evergreen Air Services, Inc

PM Testing

5/31/2005 stack PM yes

Boiler 2 Evergreen Air Services, Inc

PM Testing

5/25/2005 stack PM yes

Boiler 3 Evergreen Air Services, Inc

PM Testing

5/27/2005 stack PM no

Boiler 2 GE Energy

PM & PM10 Testing

7/8-10/2008 stack PM & PM10 no

Boiler 2 Reaction Engineering 

InternationalMercury control testing

9/21/2008 to 11/21/2008 stack mercury no

Boiler 2 GE Energy

PM & PM10 Testing

12/2-4/2008 stack PM & PM10 no

Boiler 3 Platt Environmental Services, 

IncMercury Testing

7/1/2008 stack mercury no

Boiler 2 Platt Environmental Services, 

IncMercury Testing

7/15/2008 stack mercury no

Boiler 2 GE Energy

Ammonia Emission Study

7/7/2008 stack NH3 (Ammonia) no

Boiler 1 GE Energy

ESP PECO PM Performance Test

2/18/2009 stack PM no

Boiler 1 GE Energy

ESP PM Engineering Test

2/18-19/2009 stack PM no
OMB 2060-0631 Part II, Question 12

Minnesota Power Taconite Harbor Energy Center (10075)

Boiler ID Test Date PM* SO2 HCL/HF/HCN Metal HAP Hg* CO Other organic

Unit Load 

(MW)

Net 

MWH NET)

Moisture

(%) Flow

(dscfm or Nm3/hr)

Flue gas oxygen

(%, dry) Flue gas CO2 (%, dry)

Flue gas temp

(oF)

Flue gas pressure

(atm)

Standard temp

(F)

Standard pressure

(atm)

Boiler 1 5/31/2005 Boiler 1 = 0.031 lb/mmBtu 75.4 9.94 210301 dscfm 6.27 13.5 300 29.34 68 29.92

Boiler 2 5/25/2005 Boiler 2 = 0.031 lb/mmBtu 74.5 10.41 212157 dscfm 6.2 12.23 317.1 29.08 68 29.92

Boiler 3 5/27/2005 Boiler 3 = 0.027 lb/mmBtu 72.3 10.01 197168 dscfm 6.2 13 306.4 28.94 68 28.92

Boiler 2 7/8/2008 to 7/10/2008 Test 1-3 filterable PM = 0.020 lb/mmBTU

 total PM10 =0.037 lb/mmBTU

Test 4-6 filterable PM = 0.026 lb/mmBTU

 total PM10 =0.035 lb/mmBTU

Test 7-9 filterable PM10 = 0.027 

lb/mmBTU

 total PM =0.035 lb/mmBTU

Test 10-1

Test 1-3 = 11.4

Test 4-6 = 12.0

Test 7-9 = 12.2

Test 10-12 = 12.1

Test 1-3 = 183336 dscfm

Test 4-6 = 184943 dscfm

Test 7-9 = 180534 dscfm

Test 10-12 = 182534 dscfm

Test 1-3 = 6.2 

%vol

Test 4-6 = 5.3 

%vol

Test 7-9 = 5.6 

%vol

Test 7-9 = 5.6 

%vol

Test 1-3 = 12.8 %vol

Test 4-6 = 13.6 %vol

Test 7-9 = 13.3 %vol

Test 10-12 = 13.6 %vol

Test 1-3 = 362.0 oF

Test 4-6 = 366.0 oF

Test 7-9 = 373.4 oF

Test 10-12 = 365.2 oF

Test 1-3 = 29.38

Test 4-6 = 29.39

Test 7-9 = 29.39

Test 10-12 = 29.64

Test 1-3 = 68

Test 4-6 = 68

Test 7-9 = 68

Test 10-12 = 68

Test 1-3 = 29.92

Test 4-6 = 29.92

Test 7-9 = 29.92

Test 10-12 = 29.92

Boiler 2 9/21/2008 to 11/21/2008 Mercury control testing by carbon 

trap sampling

Boiler 2 12/2/2008 to 12/4/2008 Test 1-3 filterable PM = 0.024 lb/mmBTU

 total PM10 =0.030 lb/mmBTU

Test 4-6 filterable PM = 0.027 lb/mmBTU

 total PM10 =0.037 lb/mmBTU

Test 7-9 filterable PM10 = 0.033 

lb/mmBTU

 total PM =0.041 lb/mmBTU

Test 1-3 = 10.5

Test 4-6 = 10.3

Test 7-9 = 10.5

Test 1-3 = 190024 dscfm

Test 4-6 = 193390 dscfm

Test 7-9 = 186760 dscfm

Test 1-3 = 6.0 

%vol

Test 4-6 = 5.9 

%vol

Test 7-9 = 5.9 

%vol

Test 1-3 = 13.0 %vol

Test 4-6 = 12.9 %vol

Test 7-9 = 13.0 %vol

Test 1-3 = 353.5 oF

Test 4-6 = 347.0 oF

Test 7-9 = 347.2 oF

Test 1-3 = 28.50

Test 4-6 = 28.73

Test 7-9 = 28.98

Test 1-3 = 68

Test 4-6 = 68

Test 7-9 = 68

Test 1-3 = 29.92

Test 4-6 = 29.92

Test 7-9 = 29.92

Boiler 3 7/1/2008 Total Hg = 0.49 ppb 69.5 9.0 5.8 28.71 68 29.92

Boiler 2 7/15/2008 Total Hg w/o SO3 Injection = 0.21 

ppb

Total Hg w/ SO3 Injection = 0.19 ppb 

w/o SO3 injection = 69.6 mw

w/ SO3 injection = 69.0 mw

w/o SO3 injection = 

10.9

w/ SO3 injection = 

9.3

w/o SO3 injection = 191,624 

dscfm

w/ SO3 injection = 187,077 

dscfm

w/o SO3 injection 

= 8.00

w/ SO3 injection = 

7.50

w/o SO3 injection = 

12.00

w/ SO3 injection = 

13.00

w/o SO3 injection = 360.6

w/ SO3 injection = 364.7

w/o SO3 injection = 

28.91

w/ SO3 injection = 

28.91

w/o SO3 

injection = 68

w/ SO3 injection 

= 68

w/o SO3 injection = 

29.92

w/ SO3 injection = 

29.92

Boiler 2 7/7/2008

Boiler 1 2/18/2009 22.98 lb/hr

0.0298 lb/mmBtu

75.4 11.1 170,855 dscfm 6.0 13.7 353.3 28.71 68 29.92

Boiler 1 2/18-19/2009 SO3 off ESP Voltage ~ 120 kw = 18.86 

lb/hr

SO3 off ESP Voltage ~ 120 kw = 0.0247 

lb/mmBtu

SO3 off 1 ESP Field off = 24.04 lb/hr

SO3 off 1 ESP Field off = 0.0308 lb/mmBtu

SO3 off ESP Voltage ~ 120 kw = 

75.4

SO3 off 1 ESP Field off = 75.4

SO3 off ESP Voltage ~ 120 kw = 

172,181 dscfm

SO3 off 1 ESP Field off = 

175,258 dscfm

SO3 off ESP 

Voltage ~ 120 kw 

= 5.9

SO3 off 1 ESP 

Field off = 5.9

SO3 off ESP Voltage ~ 

120 kw = 13.6

SO3 off 1 ESP Field off 

= 13.8

SO3 off ESP Voltage ~ 120 kw 

= 366.2

SO3 off 1 ESP Field off = 

360.0

SO3 off ESP 

Voltage ~ 120 kw = 

28.71

SO3 off 1 ESP 

Field off = 28.96

SO3 off ESP 

Voltage ~ 120 

kw = 68

SO3 off 1 ESP 

Field off = 68

SO3 off ESP 

Voltage ~ 120 kw = 

29.92

SO3 off 1 ESP 

Field off = 29.92

* Averaging Time = 3 - 1 hour rounds