intent to issue air emisson permit to minnesota … power...actv5: all ai's comg2: two 900...

DRAFT Air Individual Permit

Part 70 Reissuance 03100001‐009

Permittee: Minnesota Power ‐ Taconite Harbor Energy Center

Co‐permittee name: Cliffs Erie, LLC

Facility name: Minnesota Power ‐ Taconite Harbor Energy Center 8124 W Highway 61 Schroeder, MN 55613 Cook County

Operating permit issuance date: < > Expiration date: <five years after issuance date> Title I Conditions do not expire Part 70 Reissuance Permit characteristics: Federal; Part 70/Major for NSR The emission units, control equipment and emission stacks at the stationary source authorized in this permit reissue are

as described in the Permit Applications Table.

This permit reissue supersedes Air Emission Permit No. 03100001‐008 and authorizes the Permittee to operate the

stationary source at the address listed above unless otherwise noted in the permit. 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 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 SIP

under 40 CFR § 52.1220 and as such as are enforceable by EPA Administrator or citizens under the Clean Air Act.

Signature: [ ] This document has been electronically signed. for the Minnesota Pollution Control Agency

for Don Smith, P.E., Manager Air Quality Pemits Section Industrial Division

Table of Contents

Page

1. Permit applications table ............................................................................................................................................. 3 2. Where to send submittals ............................................................................................................................................ 4 3. Facility description ....................................................................................................................................................... 5 4. Summary of subject items ........................................................................................................................................... 6 5. Limits and other requirements .................................................................................................................................. 12 6. Submittal/action requirements ............................................................................................................................... 144 7. Appendices ............................................................................................................................................................... 150

Appendix A. Insignificant Activities and General Applicable Requirements Appendix B. Acid Rain Permit Application Appendix C. Parameters used in SO2 modeling Appendix D. 2016 Fugitive Emissions Control Plan Appendix E. Part 63, Subpart UUUUU Equations Appendix F. Consent Decree Definitions Appendix G. Transport Rule Requirements

Permit issued: [month day, year] 03100001‐009 Permit expires: [month day, year] of 200

1. Permit applications table Title description Application receipt date Action number Part 70 Reissuance 10/10/2003 03100001‐009 Applicability Request 02/22/2006 03100001‐006 Major Amendment 03/23/2006 03100001‐006 Applicability Request 10/01/2007 Withdrawn Major Amendment 01/18/2008 03100001‐007 Administrative Amendment 02/25/2008 Withdrawn Major Amendment 10/01/2008 03100001‐008 Administrative Amendment 01/17/2014 03100001‐009 Pre‐Application 02/18/2015 03100001‐009 Pre‐Application 02/18/2015 03100001‐009 Major Amendment 03/31/2015 03100001‐009 Major Amendment 01/14/2016 03100001‐009


2. Where to send submittals

Send submittals that are required to be submitted to the U.S. EPA regional office to: Chief Air Enforcement 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 Minn. R. 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:

Fiscal Services – 6th Floor 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 Document Coordinator notices of:

a. Accumulated insignificant activities b. Installation of control equipment c. Replacement of an emissions unit, and d. 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


3. Facility description

Allete Inc., dba Minnesota Power (Permittee) owns and operates the Taconite Harbor Energy Center (facility). The facility is a coal‐fired steam electric utility generating plant consisting of three identical tangentially‐fired coal‐burning units located at 8124 West Highway 61 in Schroeder, Cook County, Minnesota on the north shore of Lake Superior. Boilers 1 and 2 are permitted to burn bituminous and sub‐bituminous coal, as well as distillate fuel oil (which is used primarily for startup). Boiler 3 was shut down June 1, 2015 and is not permitted to operate. Each unit is capable of a heat input of 900 mmBtu/hr, with net generating capacities of 79 MW (Boiler 1) and 76 MW (Boiler 2). Currently the facility uses western subbituminous coal which is received by boat and stored in an outdoor storage pile. Ash is pneumatically conveyed to and collected in a storage bin, then wetted and disposed of at an ash disposal site. Natural gas is not available at the site at this time. Non‐contact cooling water used to supply the boiler steam condensers is drawn from Lake Superior. The facility also includes a taconite ore loading dock that is owned and operated by the Co‐permittee, Cliffs‐Erie LLC. The facility was formerly owned and operated by LTV Steel Mining Company (LTV). When owned and operated by LTV, the boilers generated electricity mostly for use by the LTV Hoyt Lakes, Minnesota taconite processing facility, with the remainder sold to the electric grid. LTV used the ore loading dock to ship the taconite produced at Hoyt Lakes. Cliffs‐Erie LLC purchased LTV's assets in 2002 and still owns and operates the dock as warranted by the taconite market.


4. Summary of subject items

SI ID: Description

Relationship Type

Related SI ID: Description

ACTV5: All AI's COMG2: Two 900 mmBtu/hr tangentially‐fired dry bottom coal‐fired boilers; REQUIREMENTS APPLY INDIVIDUALLY TO EACH COMG2 BOILER UNLESS OTHERWISE NOTED. Refer to EQUI 64 and EQUI5 for additional applicable requirements.

has members

EQUI5, EQUI64, STRU1, STRU2, TREA1, TREA2, TREA5, TREA6, TREA16, TREA17, TREA21, TREA22, TREA23, TREA24, TREA25, TREA26, TREA27, TREA28

COMG3: Hauling on Paved Roads ‐ Requirements apply individually to each COMG3 FUGI paved road subject item

has members

FUGI3, FUGI4, FUGI9, FUGI10, FUGI11, FUGI14, FUGI15, TREA15

COMG4: Pellet and Material Handling ‐ Requirements apply individually to each COMG4 FUGI subject item

has members

FUGI6, FUGI8, FUGI12, TREA34, TREA37

COMG6: Part 75 and SIP SO2 & NOx CEMS and COMS Requirements for STRU1 & STRU2 ‐ Requirements apply individually to each CEMS and each COMS on each stack unless otherwise noted. PM and Hg CEMS requirements are located in COMG7.

has members

EQUI29, EQUI30, EQUI31, EQUI42, EQUI43, EQUI45, EQUI91, EQUI92, EQUI93, EQUI94, STRU1, STRU2

COMG7: Part 63, Subpart UUUUU Requirements ‐ REQUIREMENTS

has members

EQUI5, EQUI30, EQUI43, EQUI64, EQUI95,

SI ID: Description

Relationship Type


APPLY INDIVIDUALLY TO EACH COMG7 BOILER AND MONITOR AS APPLICABLE, UNLESS OTHERWISE NOTED.

EQUI96, EQUI97, EQUI98

EQUI100: Ash Loadout; EU 013

sends to STRU13: Ash Loadout Baghouse stack; SV 013

EQUI100: Ash Loadout; EU 013

is controlled by

TREA30: Ash Loadout baghouse; CE 028

EQUI101: Diesel fire pump ‐ 1955; EU 014

sends to STRU14: Fire Pump Engine stack; SV 014

EQUI29: COMS ‐ Boiler 2; MR 033

monitors STRU2: Boiler 2 stack; SV 002

EQUI30: SO2 Monitor ‐ Boiler 2; MR 034


EQUI31: CO2 Monitor ‐ Boiler 2; MR 036


EQUI3: Crusher and Related Transfer Points; EU 011

sends to STRU11: Crusher Baghouse stack; SV 011

EQUI3: Crusher and Related Transfer Points; EU 011

is controlled by

TREA18: Crusher baghouse; CE 019







EQUI4: Heating Boiler ‐ 34 mmBtu/hr; EU 004

sends to STRU4: Heating Boiler stack; SV 004

EQUI5: Boiler No. 2; is monitored EQUI29: COMS


SI ID: Description

Relationship Type


EU 002 by ‐ Boiler 2; MR 033

EQUI5: Boiler No. 2; EU 002

is monitored by



is monitored by



sends to EQUI90: Part 75 CEMS Data Acquisition and Handling System software; DAS 004


is monitored by

EQUI93: NOx Monitor ‐ Boiler 2; MR 046


is monitored by

EQUI94: Flow Monitor ‐ Boiler 2; MR 047


is monitored by

EQUI96: PM Monitor ‐ Boiler 2; MR 049


is monitored by

EQUI98: Hg Sorbent Trap ‐ Boiler 2; MR 051


sends to STRU2: Boiler 2 stack; SV 002


is controlled by

TREA16: Ammonia injection (CE 017) upstream of CE 002 ESP


is controlled by

TREA17: SO3 Injection ‐ Boiler 2; CE 018


is controlled by

TREA21: Activated Carbon Injection ‐ Boiler 2; CE 012


is controlled by

TREA27: Sodium

SI ID: Description

Relationship Type

Related SI ID: Description Bicarbonate Injection ‐ Boiler 2; CE 025


is controlled by

TREA2: ESP ‐ cold side ‐ Boiler 2; CE 002


is controlled by

TREA5: SNCR w/urea injection & ROFA ‐ Boiler 2; CE 010


is controlled by

TREA6: Hydrated Lime Injection ‐ Boiler 2; CE 011

EQUI63: Emergency Diesel Generator (1600 hp; 1957); EU 005

sends to STRU5: Limited Use Diesel Generator stack; SV 005


is monitored by



is monitored by



is monitored by



sends to EQUI90: Part 75 CEMS Data Acquisition and Handling System software; DAS 004


is monitored by



is monitored by



is monitored by


EQUI64: Boiler No. is monitored EQUI97: Hg


SI ID: Description

Relationship Type


1; EU 001 by Sorbent Trap ‐ Boiler 1; MR 050


sends to STRU1: Boiler 1 stack; SV 001


is controlled by



is controlled by



is controlled by



is controlled by



is controlled by



is controlled by



is controlled by

TREA28: Sodium Bicarbonate Injection ‐ Boiler 1; CE 026

EQUI65: Boiler No. 3 EQUI88: Fly Ash Silo; EU 006

sends to STRU6: Fly Ash Silo Baghouse stack; SV 006

EQUI88: Fly Ash Silo; EU 006

is controlled by

TREA10: Fly Ash Silo baghouse; CE 004

EQUI89: Coal Tripper Floor; EU 007

sends to STRU7: Tripper Floor Baghouse stack; SV 007

EQUI89: Coal Tripper Floor; EU 007

is controlled by

TREA4: Tripper Floor baghouse; CE 007

SI ID: Description

Relationship Type


EQUI90: Part 75 CEMS Data Acquisition and Handling System software; DAS 004









EQUI99: Bottom Ash Silo; EU 012

sends to STRU12: Bottom Ash Silo Baghouse stack; SV 012

EQUI99: Bottom Ash Silo; EU 012

is controlled by

TREA29: Bottom Ash Silo baghouse; CE 027

FUGI10: Activated Carbon Truck Hauling ‐ Paved Road; FS 009

is controlled by

TREA15: Paved Road Sweeping; CE 016

FUGI11: Hydrated Lime Truck Hauling ‐ Paved Road; FS 010

is controlled by


FUGI12: Pellet Drop From Railcars into Dock Storage Bins; FS 001, TREA37

is controlled by

TREA37: Dust Suppression by Water Spray

FUGI13: Limestone is controlled TREA35:


SI ID: Description

Relationship Type


Storage Pile (limestone handling/TREA35; dozer traffic/TREA36; dozer blade pile maintenance; pile wind erosion); FS 003

by Limestone pile handling Water Spray

FUGI13: Limestone Storage Pile (limestone handling/TREA35; dozer traffic/TREA36; dozer blade pile maintenance; pile wind erosion); FS 003

is controlled by

TREA36: Limestone pile dozer traffic Water Spray

FUGI14: Sodium Bicarbonate Truck Hauling ‐ Paved Road; FS 014

is controlled by


FUGI15: Plant Site Truck Ash Hauling ‐ Paved Road; FS 015

is controlled by


FUGI1: Coal/Limestone Boat Unloading and Materials Handling; FS 004

is controlled by

TREA11: Dust Suppression by Water Spray; CE 005

FUGI2: Coal Storage Pile (coal handling/TREA31; dozer traffic/TREA32; dozer blade pile maintenance; pile wind erosion); FS 002

is controlled by

TREA31: Coal pile handling Water Spray

FUGI2: Coal Storage Pile (coal handling/TREA31; dozer traffic/TREA32; dozer blade pile maintenance; pile wind erosion); FS 002

is controlled by

TREA32: Coal pile dozer traffic Water Spray

SI ID: Description

Relationship Type


FUGI3: Ammonia Truck Hauling ‐ Paved Road; FS 012

is controlled by


FUGI4: Urea Truck Hauling ‐ Paved Road; FS 013

is controlled by


FUGI5: Ash Landfill (ash handling/TREA14; dozer traffic/TREA33; dozer blade ash landfill; maintenance; wind erosion); FS 008

is controlled by

TREA14: Ash LF Ash Handling Water Spray; CE 009

FUGI5: Ash Landfill (ash handling/TREA14; dozer traffic/TREA33; dozer blade ash landfill; maintenance; wind erosion); FS 008

is controlled by

TREA33: Ash LF dozer traffic Water Spray

FUGI6: Taconite Pellets Ship Loading; FS 005

FUGI7: Truck Ash Hauling ‐ Unpaved Road; FS 007

is controlled by

TREA13: Dust Suppression by Chemical Stabilizers or Wetting Agents; CE 008

FUGI8: Railcar Material Loading; FS 006, TREA34

is controlled by


FUGI9: Molten Sulfur (SO3) Truck Hauling ‐ Paved Road; FS 011

is controlled by


STRU11: Crusher Baghouse stack; SV 011

STRU12: Bottom Ash Silo Baghouse stack; SV 012

STRU13: Ash Loadout Baghouse


SI ID: Description

Relationship Type


stack; SV 013 STRU14: Fire Pump Engine stack; SV 014

STRU1: Boiler 1 stack; SV 001

is monitored by



is monitored by



is monitored by



is monitored by



is monitored by



is monitored by



is monitored by



is monitored by


STRU4: Heating Boiler stack; SV 004

STRU5: Limited Use Diesel Generator stack; SV 005

STRU6: Fly Ash Silo Baghouse stack; SV 006

STRU7: Tripper Floor Baghouse stack; SV 007

TFAC2: Minnesota Power ‐ Taconite Harbor Energy Center

SI ID: Description

Relationship Type


TREA10: Fly Ash Silo baghouse; CE 004

TREA11: Dust Suppression by Water Spray; CE 005

TREA13: Dust Suppression by Chemical Stabilizers or Wetting Agents; CE 008

TREA14: Ash LF Ash Handling Water Spray; CE 009




TREA18: Crusher baghouse; CE 019




is controlled in series by











TREA22: SNCR w/urea injection &


TREA26: Ammonia


SI ID: Description

Relationship Type


ROFA ‐ Boiler 1; CE 020

injection (CE 024) upstream of CE 001 ESP










TREA29: Bottom Ash Silo baghouse; CE 027


TREA30: Ash Loadout baghouse; CE 028

TREA31: Coal pile handling Water Spray

TREA32: Coal pile dozer traffic Water Spray

TREA33: Ash LF dozer traffic Water Spray


SI ID: Description

Relationship Type


TREA35: Limestone pile handling Water Spray

TREA36: Limestone pile dozer traffic Water Spray


TREA4: Tripper Floor baghouse; CE 007




















Permit Issued: [month day, year] 03100001‐009 Permit Expires: [month day, year] of 200

5. Limits and other requirements Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation TFAC 2 03100001 Minnesota

Power ‐ Taconite Harbor Energy Center

5.1.1 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. This permit shall not alter or affect the liability of the Permittee for any violation of applicable requirements prior to or at the time of permit issuance. [Minn. R. 7007.1800, (A)(2)]

5.1.2 PERMIT APPENDICES This permit contains appendices as listed in the permit Table of Contents. The Permittee shall comply with all requirements contained in Appendices A, B, D, E, F, and G. Modeling parameters in Appendix C are included for reference only as described elsewhere in this permit. [Minn. R. 7007.0800, subp. 2]

5.1.3 REASONABLE POSSIBILITY 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 52.21(r)(6)(vi)(b). 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,


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation recordkeeping, or notification may still be required by Minn. R. 7007.1150 ‐ 7007.1500. [Title I Condition: 40 CFR 52.21(r)(6) & Minn. R. 7007.3000]

5.1.4 Preconstruction Documentation ‐‐ Before beginning actual construction on a project, the Permittee shall document the following information: 1. Project description 2. Identification of any emission unit whose emissions of an NSR pollutant could be affected 3. Pre‐change potential emissions of any affected existing emission unit, and the projected post‐change potential emissions of any affected existing or new emission unit. 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 emission unit 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. [Minn. R. 7007.0800, subps. 4&5, Minn. R. 7007.1200, subp. 4, Title I Condition: 40 CFR 52.21(r)(6) & Minn. R. 7007.3000]

5.1.5 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. [Minn. R. 7007.0800, subps. 4&5, Title I Condition: 40 CFR 52.21(r)(6) & Minn. R. 7007.3000]

5.1.6 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. [Minn. R. 7007.0800, subps. 4&5, Title I Condition: 40 CFR 52.21(r)(6) & Minn. R. 7007.3000]


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 5.1.7 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. [Minn. R. 7007.0800, subps. 4&5, Title I Condition: 40 CFR 52.21(r)(6) & Minn. R. 7007.3000]

5.1.8 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. [Minn. R. 7007.0800, subps. 4&5, Title I Condition: 40 CFR 52.21(r)(6) & Minn. R. 7007.3000]

5.1.9 GENERAL REQUIREMENTS 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. R. 7007.0100, subp. 7(A), 7(L), & 7(M), Minn. R. 7007.0800, subp. 4, Minn. R. 7007.0800, subps. 1‐2, Minn. R. 7009.0010‐0080, Minn. Stat. 116.07, subd. 4a, Minn. Stat. 116.07, subd. 9]

5.1.10 The Permittee shall comply with the General Conditions listed in Minn. R. 7007.0800, subp. 16. [Minn. R. 7007.0800, subp. 16]

5.1.11 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.


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 7011.0150. [Minn. R. 7011.0150]

5.1.12 Comply with Fugitive Emissions Control Plan: Follow the actions and recordkeeping specified in the control plan (Appendix D). 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]

5.1.13 Air Pollution Control Equipment: Operate all pollution control equipment whenever the corresponding process equipment and emission units are operated, unless otherwise noted in this permit. [Minn. R. 7007.0800, subp. 16(J), Minn. R. 7007.0800, subp. 2]

5.1.14 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, Minn. R. 7007.0800, subp. 16(J), Minn. R. 7007.0800, subp. 2]

5.1.15 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. 7030.0010‐0080]

5.1.16 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]

5.1.17 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)]

5.1.18 Performance Testing: Conduct all performance tests in accordance with Minn. R. ch. 7017 unless otherwise noted in this permit. [Minn. R. ch. 7017]

5.1.19 Performance Test Notifications and Submittals: Performance Tests are due as required in this permit. Performance Test Notification (written): due 30 days before


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 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 ‐ Compact Disk 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, Minn. R. 7017.2035, subp. 1, Minn. R. 7017.2035, subp. 2]

5.1.20 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]

5.1.21 Operation of Monitoring Equipment: Unless otherwise noted in this permit, 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)]

5.1.22 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)]

5.1.23 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)]

5.1.24 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)]

5.1.25 If the Permittee determines that no permit amendment or


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 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]

5.1.26 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]

5.1.27 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]

5.1.28 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]

5.1.29 Breakdown Notifications: Notify the Commissioner within 24


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 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]

5.1.30 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. Upon adoption of a new or amended federal applicable requirement, and if there are more than 3 years remaining in the permit term, the Permittee shall file an application for an amendment within nine months of promulgation of the applicable requirement, pursuant to Minn. R. 7007.0400, subp. 3. The preceding sentence does not apply if the effective date of the requirement is later than the date on which the permit is due to expire. [Minn. R. 7007.0400, subp. 3, Minn. R. 7007.1150‐7007.1500]

5.1.31 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]

5.1.32 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). Performance testing deadlines from the General Provisions of 40 CFR pt. 60 and pt. 63 are examples of deadlines for which the MPCA does not have authority to grant extensions and therefore such requests can not be accommodated by Minn. R. 7007.1400, subp. 1(H). [Minn. R. 7007.1400, subp. 1(H)]

5.1.33 Emission Fees: due 60 days after receipt of an MPCA bill [Minn.


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation R. 7002.0005‐7002.0095]

5.1.34 Emission Inventory Report: due on or before April 1 of each calendar year following permit issuance. Submit the report on a form approved by the Commissioner. [Minn. R. 7019.3000, Minn. R. 7019.3010]

5.1.35 TRANSPORT RULE REQUIREMENTS The Permittee must comply with all the applicable requirements in 40 CFR pt. 97 for the NOx Annual Trading Program and the SO2 Group 2 Trading Program. These requirements are located in Appendix H of this permit. [40 CFR 52.1240, 40 CFR pt. 97, Minn. R. 7007.0800, subp. 2]

5.1.36 SO2 MODELING Modeled Parameters for SO2: The parameters used in SO2 modeling approved August 10, 2015 for permit number 03100001‐009 are listed in Appendix C of this permit. The parameters describe the operation of the facility at maximum permitted capacity. The purpose of listing the parameters in the appendix is to provide a benchmark for future changes. [Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M), Minn. R. 7007.0800, subp. 4, Minn. R. 7007.0800, subps. 1‐2, Minn. R. 7009.0010‐7009.0080, Minn. Stat. 116.07, subd. 4a, Minn. Stat. 116.07, subd. 9]

5.1.37 Changes To 1‐Hour SO2 Modeled Parameters: If the Permittee desires to change any parameter used in 1‐hour SO2 modeling listed in permit Appendix C, the Permittee shall obtain written approval from the MPCA before making any change. MPCA written approval of changes affecting any modeled SO2 parameter applies only to the re‐modeling determination. Any written approval regarding re‐modeling does not exempt the Permittee from obtaining any required permit or permit amendment for making such change(s), and any written approval does not take the place of any permit or permit amendment that may be required due to such change(s). [Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M), Minn. R. 7007.0800, subp. 4, Minn. R. 7007.0800, subps. (1‐2), Minn. R. 7009.0020‐7009.0080, Minn. Stat. 116.07, subd. 4a, Minn. Stat. 116.07, subd. 9]

COMG 2 GP001 Two 900

mmBtu/hr tangentially‐fired dry bottom coal‐fired boilers; REQUIREMENTS APPLY


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation INDIVIDUALLY TO EACH COMG2 BOILER UNLESS OTHERWISE NOTED. Refer to EQUI 64 and EQUI5 for additional applicable requirements.

5.2.1 Test Burns: Alternative fuels may be used in EQUI64 and/or EQUI5 during test burns according to the following requirements: 1. The significant emissions increase and the net emissions increase of any criteria pollutant (regulated under 40 CFR Section 52.21) due to combusting alternative fuels (compared to the emissions from combusting subbituminous coal) does not exceed any emission increase threshold at 40 CFR Section 52.21(b)(23)(i) and (ii) during any 12‐month period. The Permittee shall verify this by calculating the difference between the emissions that will result from the test burn, as well as the emissions that would occur if subbituminous coal was combusted during the period of time when the alternative fuel was burned for each test burn, and summing these data on a pollutant‐by‐pollutant basis, for all test burns during each 12‐month period. The two‐step process specified at 40 CFR Section 52.21(a)(2)(iv)(a) shall be used to determine the change in emissions. 2. Permit emission limits are not exceeded. The Permittee shall verify this during the test burn by using PM, SO2, NOx, and Hg continuous emission monitors, and a continuous opacity monitor. For emissions not continuously monitored, the Permittee shall verify limits are not exceeded by calculating emissions using AP‐42 or other available emission factors. 3. Alternative fuels that are solid wastes, as defined in 40 CFR Section 258.2, shall not be burned unless determined to not be solid waste when combusted according to 40 CFR Section 241.3 or 40 CFR Section 241.4. Wood burned must meet the definition of "Clean Cellulosic Biomass" found in 40 CFR Section 241.2. Used oil must meet the specifications outlined in 40 CFR Section 279.11. 4. Test burns shall only be conducted to determine the feasibility of the alternative fuel type for the emission source, and shall be conducted only for as long as necessary to make


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation the determination. 5. For each alternative fuel test burn, the Permittee shall keep records of: a) the date and time of the start and stop of the alternative fuel test burn, b) the quantity, type, and characteristics (heat content in Btu/lb, ash content, moisture content, contaminant content, as applicable) of the alternative fuel used during each test burn, c) the actual emissions that will result from each alternative fuel test burn, and d) the actual emissions that would occur if subbituminous coal was combusted during the test burn time period, e) the actual emissions increase that will occur from the test burn of the alternative fuel compared to the emissions that would occur if subbituminous coal was combusted during the test burn time period. f) the net emissions increase for each pollutant regulated under 40 CFR Section 52.21 from all test burns during the previous 12‐month period. These records shall be made no later than 24 hours after completion of each test burn except item 5c shall be calculated and recorded prior to each test burn. [40 CFR pt. 241, Minn. R. 7007.0800, subp. 2]

5.2.2 The Permittee is authorized to inject coal pile run off water into COMG2 boilers at a maximum total Water flow rate <= 5.0 gallons per minute, subject to the following conditions: 1. coal pile run off shall contain a maximum 250 mg solids per liter of run off determined by weekly sampling and analysis to determine the run off solids content in mg per liter; 2. records shall be kept for each day run off is injected into any COMG2 boiler of the number of gallons injected, the average application rate in gallons per minute, the start and stop times of run off water injection, and the solids content data from sampling for each time period of run off injection; 3. This 5 gallon per minute limit applies to the total run off injected into both boilers during any one‐minute period. The Permittee shall not inject coal pile run off into the boiler if this process violates any other permit that the facility holds or any other Minnesota or federal rule or law. Note this process is not for disposal of such run off because this run off injection takes the place of water injected by the


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation Permittee into the boilers along with urea injection as part of the Selective Noncatalytic Reduction NOx control equipment (TREA5 and TREA22) for each COMG2 boiler, and therefore this run off injection is not subject to 40 CFR pt. 241 'Solid Wastes Used As Fuels Or Ingredients In Combustion Units'. [Minn. R. 7007.0800, subp. 2]

5.2.3 ACID RAIN PROGRAM REQUIREMENTS Comply with the applicable Acid Rain emissions limitation for sulfur dioxide. [40 CFR 72.9(c)(1)(ii), 40 CFR 72.9(g)(4)]

5.2.4 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 (Boswell Energy Center) 1, 2, 3, 4 Syl Laskin (Laskin Energy Center) 1, 2 Taconite Harbor (Taconite Harbor Energy Center) 1, 2, 3. [40 CFR 76.11]

5.2.5 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 72.9(f)(1)]

5.2.6 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 72.30(c)]


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 5.2.7 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 72.21]

5.2.8 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 75.10]

5.2.9 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 72.9(c)(1)(i), 40 CFR 72.9(g)(4)]

5.2.10 CONSENT DECREE REQUIREMENTS The Permittee is subject to the requirements of a Consent Decree filed as CASE 0:14‐cv‐02911‐ADM‐LIB Document 3‐1 on July 16, 2014 and signed by the Judge of the U.S. District Court for Minnesota on September 29, 2014, hereinafter referred to as the 'Consent Decree'. Appendix F of this permit contains Consent Decree definitions relevant to this permit and the facility. Please refer to the Consent Decree for additional definitions that may not be contained in Appendix F. For any conflicts or discrepancies between the requirements and definitions in the Consent Decree and the requirements and definitions in this permit, the Consent Decree shall prevail. [CAAA of 1990, Minn. R. 7007.0100, subp. 7, Minn. R. 7007.0800, subp. 1&2, Minn. Stat. 116.07, subd. 4a&9, Title I Condition: 40 CFR 52.21]

5.2.11 "Continuous Operation" and "Continuously Operate" mean that when a pollution control technology or combustion control is required to be used at a Unit pursuant to the Consent Decree (including, but not limited to a baghouse, dry sorbent injection system, electrostatic precipitator, flue gas desulfurization system, furnace sorbent injection system, low nitrogen oxides burner, over fire air system, rotating opposed fire air system, selective catalytic reduction device, selective non‐catalytic reduction device, wet particulate scrubber, and/or wet venturi/ESP device) it shall be operated at all times such Unit is in operation (except as otherwise provided by Consent Decree Section XV Force Majeure), consistent with the technological limitations, manufacturers' specifications,


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation good engineering and maintenance practices, and good air pollution control practices for minimizing emissions (as defined in 40 CFR Section 60.11(d)) for such equipment and the Unit. Note: Taconite Harbor Energy Center Coal‐Fired Electric Generating Units are not controlled by a baghouse, flue gas desulfurization, selective catalytic reduction, wet particulate scrubber, or a wet venture/ESP device (however, these devices are present at the Permittee's other electric generating facilities that are also subject to the Consent Decree ). [CAAA of 1990, Minn. R. 7007.0100, subp. 7, Minn. R. 7007.0800, subp. 1&2, Minn. Stat. 116.07, subd. 4a&9, Title I Condition: 40 CFR 52.21]

5.2.12 The Permittee shall Continuously Operate the ROFA system and SNCR control device (TREA22 and TREA5 for EQUI64 and EQUI5, respectively) to achieve and maintain Nitrogen Oxides <= 0.160 pounds per million Btu heat input as a 30‐Day Rolling Average NOx Emission Rate for each boiler (EQUI64 and EQUI5). "ROFA" means a process by which air is injected into the furnace via rotating, asymmetrically placed air nozzles designed to generate turbulence and reduce NOx. "SNCR" means an air pollution control process for the reduction of NOx emissions through the injection of ammonia or urea into the boiler. ROFA and SNCR collectively comprise TREA22 for boiler 1 (EQUI64), and collectively comprise TREA5 for boiler 2 (EQUI5). [CAAA of 1990, Minn. R. 7007.0100, subp. 7, Minn. R. 7007.0800, subp. 1&2, Minn. Stat. 116.07, subd. 4a&9, Title I Condition: 40 CFR 52.21]

5.2.13 The Permittee shall not exceed the following System‐Wide Annual Tonnage Limitation for NOx emissions: Nitrogen Oxides <= 6700 tons per year on a calendar year basis. The Minnesota Power System is composed of Boswell Energy Center, Laskin Energy Center, Rapids Energy Center, and Taconite Harbor Energy Center. [CAAA of 1990, Minn. R. 7007.0100, subp. 7, Minn. R. 7007.0800, subp. 1&2, Minn. Stat. 116.07, subd. 4a&9, Title I Condition: 40 CFR 52.21]

5.2.14 NOx Emissions Monitoring: In determining a 30‐Day Rolling Average Emission Rate for NOx, the Permittee shall use a Continuous Emissions Monitoring System ("CEMS") in accordance with the procedures of 40 CFR Part 75 and 40 CFR Part 60, Appendix F, Procedure 1, except that emissions data for the 30‐Day Rolling Average Emission Rate need not be bias adjusted and the missing data substitution procedures of 40 CFR Part 75 shall not apply.


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation For purposes of determining compliance with the NOx System‐Wide Annual Tonnage Limitation, the Permittee shall use CEMS in accordance with the procedures at 40 CFR Part 75. [CAAA of 1990, Minn. R. 7007.0100, subp. 7, Minn. R. 7007.0800, subp. 1&2, Minn. Stat. 116.07, subd. 4a&9, Title I Condition: 40 CFR 52.21]

5.2.15 Surrender of NOx Allowances: Except as provided in the Consent Decree, beginning in calendar year 2014 and continuing each calendar year thereafter, the Permittee shall not sell, bank, trade, or transfer any NOx Allowances allocated to the Minnesota Power System for that calendar year. Beginning in calendar year 2014 and continuing each calendar year thereafter, the Permittee shall Surrender all NOx Allowances allocated to Units within the Minnesota Power System for that calendar year (other than those NOx Allowances that the Permittee needs to meet federal and/or state Clean Air Act regulatory requirements for the Minnesota Power System Units). Nothing in the Consent Decree shall prevent the Permittee from purchasing or otherwise obtaining NOx Allowances from another source to the extent otherwise allowed by law. The requirements of the Consent Decree pertaining to the Permittee's use and Surrender of NOx Allowances are permanent injunctions not subject to any termination provision of the Consent Decree. [CAAA of 1990, Minn. R. 7007.0100, subp. 7, Minn. R. 7007.0800, subp. 1&2, Minn. Stat. 116.07, subd. 4a&9, Title I Condition: 40 CFR 52.21]

5.2.16 Super‐Compliant NOx Allowances: Notwithstanding the Surrender of Allowances requirement, in each calendar year beginning in 2014, and continuing thereafter, the Permittee may sell, bank, use, trade, or transfer NOx Allowances made available in each calendar year solely as a result of: (a) the installation and operation of any NOx pollution control equipment that is not otherwise required by, or necessary to maintain compliance with, any provision of the Consent Decree, and is not otherwise required by law, or the installation and operation of pollution control equipment prior to the dates required under the Consent Decree or otherwise required by law; or (b) achievement and maintenance of an emission rate below


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation the Calendar Year Average Emission Rate for NOx equal to the lesser of (i) ninety percent of an applicable 30‐Day Rolling Average Emission Rate for NOx, or (ii) an applicable 12‐Month Rolling Average Emission Rate for NOx, provided the Permittee is also in compliance for that calendar year with all emission limitations for NOx set forth in the Consent Decree. [CAAA of 1990, Minn. R. 7007.0100, subp. 7, Minn. R. 7007.0800, subp. 1&2, Minn. Stat. 116.07, subd. 4a&9, Title I Condition: 40 CFR 52.21]

5.2.17 Method for Surrender of NOx Allowances: The Permittee shall Surrender all NOx Allowances required to be Surrendered pursuant to the requirements for Surrender of Allowances subject to Super‐Compliant Allowances in this permit, by April 30 of the immediately following calendar year. For all NOx Allowances required to be Surrendered, the Permittee shall first submit a NOx Allowance transfer request to EPA's Office of Air and Radiation's Clean Air Markets Division directing the transfer of such NOx Allowances to the EPA Enforcement Surrender Account or to any other EPA account that EPA may direct in writing. Such NOx Allowance transfer requests may be made in an electronic manner using the EPA's Clean Air Markets Division Business System or similar system provided by EPA. As part of submitting these transfer requests, the Permittee shall irrevocably authorize the transfer of these NOx Allowances and identify, by name of account and any applicable serial or other identification numbers or station names, the source and location of the NOx Allowances being Surrendered. [CAAA of 1990, Minn. R. 7007.0100, subp. 7, Minn. R. 7007.0800, subp. 1&2, Minn. Stat. 116.07, subd. 4a&9, Title I Condition: 40 CFR 52.21]

5.2.18 The Permittee shall Continuously Operate DSI (sodium bicarbonate injection TREA28 and TREA27 for EQUI64 and EQUI5, respectively) and/or FSI (hydrated lime injection TREA23 and TREA6 for EQUI64 and EQUI5, respectively) to achieve and maintain Sulfur Dioxide <= 0.300 pounds per million Btu heat input as a 30‐Day Rolling Average SO2 Emission Rate for each boiler (EQUI64 and EQUI5). "Dry Sorbent Injection" or "DSI" means a process in which a sorbent (sodium bicarbonate) is injected into the flue gas ductwork downstream of the boiler and upstream of the PM Control Device. "Furnace Sorbent Injection" or "FSI" means the process that involves injecting dry sorbent (hydrated lime) into the upper furnace of a boiler to reduce SO2 emissions by forming solid products that can be captured by particulate control equipment and later removed. [CAAA of 1990, Minn. R.


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 7007.0100, subp. 7, Minn. R. 7007.0800, subp. 1&2, Minn. Stat. 116.07, subd. 4a&9, Title I Condition: 40 CFR 52.21]

5.2.19 The Permittee shall not exceed the following System‐Wide Annual Tonnage Limitation for SO2 emissions: Sulfur Dioxide <= 7400 tons per year on a calendar year basis for 2016, Sulfur Dioxide <= 7000 tons per year on a calendar year basis for 2017 and 2018, and Sulfur Dioxide <= 3000 tons per year on a calendar year basis for 2019 and thereafter. The Minnesota Power System is composed of Boswell Energy Center, Laskin Energy Center, Rapids Energy Center, and Taconite Harbor Energy Center. [CAAA of 1990, Minn. R. 7007.0100, subp. 7, Minn. R. 7007.0800, subp. 1&2, Minn. Stat. 116.07, subd. 4a&9, Title I Condition: 40 CFR 52.21]

5.2.20 Monitoring of SO2 Emissions In determining a 30‐Day Rolling Average Emission Rate for SO2, the Permittee shall use a Continuous Emissions Monitoring System (CEMS) in accordance with the procedures of 40 CFR Part 75 and 40 CFR Part 60, Appendix F, Procedure 1, except that SO2 emissions data for the 30‐Day Rolling Average Emission Rate for SO2 need not be bias adjusted and the missing data substitution procedures of 40 CFR Part 75 shall not apply. For purposes of determining compliance with the System‐Wide Annual Tonnage Limitation for SO2, the Permittee shall use a CEMS in accordance with the procedures specified in 40 CFR Part 75. [CAAA of 1990, Minn. R. 7007.0100, subp. 7, Minn. R. 7007.0800, subp. 1&2, Minn. Stat. 116.07, subd. 4a&9, Title I Condition: 40 CFR 52.21]

5.2.21 Surrender of SO2 Allowances: Except as provided in the Consent Decree, beginning in calendar year 2014 and continuing each calendar year thereafter, the Permittee shall not sell, bank, trade, or transfer any SO2 Allowances allocated to the Minnesota Power System for that calendar year. Beginning in calendar year 2014 and continuing each calendar year thereafter, the Permittee shall Surrender all SO2 Allowances allocated to Units within the Minnesota Power System for that calendar year (other than those SO2 Allowances that the Permittee needs to meet federal and/or state Clean Air Act regulatory requirements for the Minnesota Power System Units). Nothing in the Consent Decree shall prevent the Permittee from purchasing or otherwise obtaining SO2 Allowances from another source to the extent otherwise allowed by law.


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation The requirements of the Consent Decree pertaining to the Permittee's use and Surrender of SO2 Allowances are permanent injunctions not subject to any termination provision of the Consent Decree. [CAAA of 1990, Minn. R. 7007.0100, subp. 7, Minn. R. 7007.0800, subp. 1&2, Minn. Stat. 116.07, subd. 4a&9, Title I Condition: 40 CFR 52.21]

5.2.22 Super‐Compliant SO2 Allowances: Notwithstanding the Surrender of Allowances requirement, in each calendar year beginning in 2014, and continuing thereafter, the Permittee may sell, bank, use, trade, or transfer SO2 Allowances made available in each calendar year solely as a result of: (a) the installation and operation of any SO2 pollution control equipment that is not otherwise required by, or necessary to maintain compliance with, any provision of the Consent Decree, and is not otherwise required by law, or the installation and operation of pollution control equipment prior to the dates required under the Consent Decree or otherwise required by law; or (b) achievement and maintenance of an emission rate below the Calendar Year Average Emission Rate for SO2 equal to the lesser of (i) ninety percent of an applicable 30‐Day Rolling Average Emission Rate for SO2, or (ii) an applicable 12‐Month Rolling Average Emission Rate for SO2, provided the Permittee is also in compliance for that calendar year with all emission limitations for SO2 set forth in the Consent Decree. The Permittee shall timely report the generation of such super‐compliant SO2 Allowances to EPA and MPCA in accordance with Consent Decree Section XII (Periodic Reporting). [CAAA of 1990, Minn. R. 7007.0100, subp. 7, Minn. R. 7007.0800, subp. 1&2, Minn. Stat. 116.07, subd. 4a&9, Title I Condition: 40 CFR 52.21]

5.2.23 Method for Surrender of SO2 Allowances: The Permittee shall Surrender all SO2 Allowances required to be Surrendered pursuant to the requirements for Surrender of Allowances subject to Super‐Compliant Allowances in this permit, by April 30 of the immediately following calendar year. For all SO2 Allowances required to be Surrendered, the Permittee shall first submit an SO2 Allowance transfer request to EPA's Office of Air and Radiation's Clean Air Markets Division directing the transfer of such SO2 Allowances to the EPA Enforcement Surrender Account or to any other EPA account that EPA may direct in writing. Such SO2 Allowance


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation transfer requests may be made in an electronic manner using the EPA's Clean Air Markets Division Business System or similar system provided by EPA. As part of submitting these transfer requests, the Permittee shall irrevocably authorize the transfer of these SO2 Allowances and identify, by name of account and any applicable serial or other identification numbers or station names, the source and location of the SO2 Allowances being Surrendered. [CAAA of 1990, Minn. R. 7007.0100, subp. 7, Minn. R. 7007.0800, subp. 1&2, Minn. Stat. 116.07, subd. 4a&9, Title I Condition: 40 CFR 52.21]

5.2.24 Optimization of Electrostatic Precipitators The Permittee shall Continuously Operate each existing PM Control Device (TREA1 and TREA2 for EQUI64 and EQUI5, respectively) on each Unit at the facility to maximize PM emission reductions at all times when each Unit is in operation. Except as required during correlation testing under 40 CFR Part 60, Appendix B, Performance Specification 11, and Quality Assurance Requirements under Appendix F, Procedure 2, as required by the Consent Decree, the Permittee shall, at a minimum, ensure that to the extent practicable each section of each ESP at such Unit is fully energized; (b) the automatic control systems on each Electrostatic Precipitator at such Unit are operated to maximize PM collection efficiency, where applicable; (c) each opening in the casings, ductwork, and expansion joints for each ESP at such Unit is inspected and repaired during the next planned Unit outage (or unplanned outage of sufficient length) to minimize air leakage; (d) the power levels delivered to each ESP at such Unit are maintained, where applicable, consistent with manufacturers' specifications, the operational design of the Unit, and good engineering practices; (e) the plate‐cleaning and discharge‐electrode‐cleaning systems for each ESP at such Unit are optimized, where applicable, by varying the cycle time, cycle frequency, rapper‐vibrator intensity, and number of strikes per cleaning event. [CAAA of 1990, Minn. R. 7007.0100, subp. 7, Minn. R. 7007.0800, subp. 1&2, Minn. Stat. 116.07, subd. 4a&9, Title I Condition: 40 CFR 52.21]

5.2.25 Filterable Particulate Matter <= 0.030 pounds per million Btu heat input as a 3‐hour average. [CAAA of 1990, Minn. R. 7007.0100, subp. 7, Minn. R. 7007.0800, subp. 1&2, Minn. Stat. 116.07, subd. 4a&9, Title I Condition: 40 CFR 52.21]

5.2.26 Stack testing shall be used to determine compliance with the (filterable) PM emission limits established by the Consent Decree. Refer to Section 6.2 in 'Submittal/action requirements' of this permit for COMG2 boilers PM stack testing requirements. [CAAA of 1990, Minn. R. 7007.0100, subp. 7, Minn. R.


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 7007.0800, subp. 1&2, Minn. Stat. 116.07, subd. 4a&9, Title I Condition: 40 CFR 52.21]

5.2.27 Prohibition On Netting Credits or Offsets: Emission reductions that result from actions to be taken by the Permittee after the (September 29, 2014) date of entry of the Consent Decree to comply with the requirements of the Consent Decree, shall not be considered as a creditable contemporaneous emission decrease for the purpose of obtaining a Netting credit or offset under the Clean Air Act's PSD and Nonattainment NSR programs. Notwithstanding the preceding sentence, and subject to the limitations provided below, the Permittee may treat up to (a) 75 tons of NOx, 75 tons of SO2, and 15 tons of PM emission reductions at Boswell Units 3 and 4 as if they were not otherwise required by the Consent Decree for purposes of Netting at the Boswell Units 3 and 4. Use of the Netting credits provided in the previous paragraph is subject to the following additional restrictions: (a) The emission reductions of NOx, SO2, and PM that the Permittee intends to utilize for Netting purposes must be contemporaneous and otherwise creditable within the meaning of the Act and the applicable SIP, and the Permittee must comply with, and be subject to, all requirements and criteria for creating contemporaneous creditable decreases as set forth in 40 CFR Section 52.21(b) and the applicable SIP, subject to the limitations of Section VIII of the Consent Decree, (b) The Permittee must apply for, and obtain, any required major or minor NSR permits for any project in which emission reductions under the first paragraph of this requirement are used for Netting. The Permittee shall provide notice and a copy of its permit application to EPA in accordance with Section XIX (Notices) of the Consent Decree, concurrent with its permit application submission to the relevant permitting authority, (c) The emission reductions of NOx, SO2, and PM that the Permittee intends to utilize for netting shall not be available under this requirement if such use would result in an exceedance of a PSD increment, or an interference with "reasonable further progress" toward attainment of a NAAQS in accordance with Part D of Title I of the CAA, and (d) The Permittee must be and remain in full compliance with the provisions of the Consent Decree establishing performance, operational, maintenance, and control technology requirements at Boswell Units 3 and 4, including


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation emission rates, system‐wide annual tonnage limitations, and the requirements pertaining to the surrender of SO2 allowances and NOx allowances. The limitations on the generation and use of netting credits and offsets set forth in the Consent Decree do not apply to emission reductions achieved by a particular Minnesota Power System Unit that are greater than those required under the Consent Decree for that particular Minnesota Power System Unit. For purposes of this paragraph, emission reductions from a Minnesota Power System Unit are greater than those required under the Consent Decree if they result from such Unit's compliance with federally‐enforceable emission limits that are more stringent than the limits imposed on the Unit under the Consent Decree and under applicable provisions of the Clean Air Act. Nothing in the Consent Decree is intended to preclude the emission reductions generated under the Consent Decree from being considered by the applicable state regulatory agency or EPA for the purpose of attainment demonstrations submitted pursuant to Section 110 of the Act, 42 U.S.C. Section 7410, or in determining impacts on National Ambient Air Quality Standards, PSD increment, or air quality related values, including visibility, in a Class I area. [CAAA of 1990, Minn. R. 7007.0100, subp. 7, Minn. R. 7007.0800, subp. 1&2, Minn. Stat. 116.07, subd. 4a&9, Title I Condition: 40 CFR 52.21]

5.2.28 CONTROL OF MERCURY FROM ELECTRIC GENERATING UNITS Applicability. The Permittee must comply with Minn. R. 7011.0561, except as provided under Minn. R. 7011.0561, subp. 3, for any of the its coal‐fired electric generating units that the Permittee has demonstrated has actual mercury emissions of five pounds per year or more. [Minn. R. 7011.0561, subp. 1]

5.2.29 Exemption. One or both of the Permittee's electric generating units is not subject to Minn. R. 7011.0561 if such unit does not: A. emit five pounds of mercury per year or more as demonstrated in Minn. R. 7011.0561, subp. 9; B. combust coal for more than ten percent of the average annual heat input during any three consecutive calendar years; or C. combust coal for more than 15 percent of the annual heat input during any calendar year. [Minn. R. 7011.0561, subp. 3]

5.2.30 Performance standards for mercury. Unless the commissioner establishes an alternative mercury emissions reduction under


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation Minnesota Statutes, section 216B.687, subdivision 3, the Permittee must control mercury emissions as described in Minn. R. 7011.0561, subp. 4 (as shown below) for any of the Permittee's units that doesn't qualify for the exemption in Minn. R. 7011.0561, subp. 3. (The commissioner has not established an alternative mercury emissions reduction under Minn. Stat. section 216B.687, subd. 3 as of the issuance date of this permit.) B. By January 1, 2025, the Permittee must: (1) control mercury from each COMG2 unit such that at least 70 percent of the mercury present in the fuel is captured and not emitted; or (2) demonstrate that each COMG2 unit emits no more than 2.3 pounds of mercury per Tbtu of heat input. [Minn. R. 7011.0561, subp. 4]

5.2.31 Monitoring mercury emissions. The owners or operators of a coal‐fired EGU must monitor mercury emissions as described in Minn. R. 7011.0561, subp. 5. [Minn. R. 7011.0561, subp. 5]

5.2.32 If for any of the Permittee's electric generating units the Permittee does not use a CEMS or a sorbent trap monitoring system to monitor mercury, the Permittee must conduct performance testing for mercury according to Minn. R. 7011.0561, subp. 5(B) at least once every 12 months and must complete the test no more than 13 months after the previous test. The initial test must be conducted by January 1, 2025. The Permittee may conduct performance stack tests for mercury no less frequently than once every three years, but no longer than 37 months after the previous performance test, if: (i) the performance tests for at least the immediately preceding three consecutive years show mercury reduction is greater than or equal to 85 percent; or (ii) mercury emissions are at or below 1.2 pounds of mercury per Tbtu of heat input; and, in both cases, if there are no changes in the operation of the EGU or air pollution control equipment that could increase emissions. The Permittee must resume annual performance stack tests if the test results show mercury reduction is less than 85 percent or mercury emissions are above 1.2 pounds of mercury per Tbtu of heat input. Subitems (1) to (3) below apply to performance testing conducted under Minn. R. 7011.0561, subp. 5(B). (1) Performance testing must be conducted using Code of Federal Regulations, title 40, part 60, Appendix A‐8, Method 30B. The initial performance test must be conducted for 30 boiler operating days under all process operating conditions. Sorbent traps must be used no longer than ten boiler


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation operating days. Subsequent performance tests may be ten boiler operating days long. (2) Compliance is determined by calculating the average mercury concentration from all sorbent trap results. (3) Performance testing must be conducted according to Minn. R. 7017.2001 to 7017.2060 unless modified by Minn. R. 7011.0561, subp. 5. [Minn. R. 7011.0561, subp. 5(B)]

5.2.33 Monitoring provisions; sorbent trap monitoring system. A. If the Permittee uses a sorbent trap monitoring system to monitor mercury emissions, the Permittee must follow the monitoring provisions under Minn. R. 7011.0561, subp. 7 for the measurement of mercury. "Sorbent trap monitoring system" means the equipment necessary to monitor mercury emissions continuously by using paired sorbent traps containing iodated charcoal or other sorbent medium. The system consists of sample acquisition, transport, conditioning, sorbent traps, and an automated data acquisition and handling system. The system samples the stack gas at a constant proportional rate relative to the stack gas volumetric flow rate. The sampling is a batch process. The average mercury concentration in the stack gas for the sampling period is determined, in units of micrograms per dry standard cubic meter (ug/dscm), based on the sample volume measured by the gas flow meter and the mass of mercury collected in the sorbent traps. The use of a sorbent trap monitoring system also requires the installation and certification of a stack gas flow monitor to maintain the ratio of stack gas flow rate to sample flow rate. [Minn. R. 7011.0561, subp. 7(A)]

5.2.34 Demonstrating applicability of mercury control requirements. If the Permittee does not use a CEMS or a sorbent trap monitoring system to monitor mercury on either or both COMG2 electric generating units, the Permittee for each electric generating unit without a continuous mercury monitor must conduct a 28 to 30 operating day performance test to determine the mercury mass emissions according to Minn. R. 7011.0561, subp. 9. The initial test must be completed by September 29, 2015. The Permittee must: A. conduct performance tests according to Minn. R. 7017.2001 to 7017.2060. When preparing the test plan required in Minn. R. 7017.2030, the Permittee must identify parametric data for air pollution control devices in place during the performance test that will be recorded; B. use CFR, title 40, part 60, Appendix A‐8, Method 30B, or a substantially similar alternative method approved by the


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation commissioner; C. locate the Method 30B sampling probe tip at a point within the ten percent centroidal area of the duct at a location selected according to Method 1 in CFR, title 40, part 60, Appendix A‐1, and conduct at least three nominally equal length test runs over the 28‐ to 30‐day test period. Test runs may not be longer than ten days; D. collect diluents gas data over the corresponding time period using CFR, title 40, part 60, Appendix A‐2, Method 3A, or a diluent gas monitor certified according to CFR, title 40, part 75; E. for calculation of pounds per year of mercury, collect: (1) stack gas flow rate using Method 2, 2F, or 2G in CFR, title 40, part 60, Appendix A‐1 or A‐2, or a flow rate monitor that has been certified according to CFR, title 40, part 75; and (2) moisture data using Method 4 in CFR, title 40, part 60, Appendix A‐3, or a moisture monitor certified according to CFR, title 40, part 75; F. calculate the average mercury concentration, in micrograms per cubic meter (ug/m3), for the 28‐ to 30‐day performance test, as the arithmetic average of all sorbent trap results. The Permittee must calculate the average CO2 or O2 concentration for the test period. The Permittee must use the average mercury concentration and diluents gas values to express the performance test results in units of pounds of mercury per trillion British thermal units (lb/Tbtu) and actual pounds of mercury emitted per year, using the expected fuel heat input over a one‐year period. Alternatively, the Permittee must calculate pounds of mercury emitted per year using the average mercury concentration, average stack gas flow rate, average stack gas moisture, and maximum operating hours per year; G. record parametric data for air pollution control devices in place during the performance test. If the calculation in item F demonstrates that the EGU emits less than five pounds per year of mercury, the Permittee must operate air pollution control equipment at the rates exhibited during the performance test; and H. repeat the performance test once every five years to demonstrate that the mercury emissions from the EGU remain below five pounds per year. [Minn. R. 7011.0561, subp. 9]


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 5.2.35 Incorporations by reference. For purposes of Minn. R.

7011.0561, the methods listed in Minn. R. 7011.0561, subp. 10, items A and B are incorporated by reference, as amended. These documents are subject to frequent change. [Minn. R. 7011.0561, subp. 10]

COMG 3 GP003 Hauling on Paved

Roads ‐ Requirements apply individually to each COMG3 FUGI paved road subject item

5.3.1 Paved Haul Road Fugitive Emissions Control: The Permittee shall follow the practices described in the current Fugitive Emissions Control Plan for control of fugitive emissions from COMG3 fugitive emission sources. The Plan currently specifies that practices for fugitive dust control at a minimum shall include sweeping of paved road surfaces (TREA15) at the frequency specified in the Plan. [Minn. R. 7011.0150, Title I Condition: Avoid major modification under 40 CFR 52.21(b)(2) and Minn. R. 7007.3000]

COMG 4 GP004 Pellet and

Material Handling ‐ Requirements apply individually to each COMG4 FUGI subject item

5.4.1 The Permittee shall follow the practices described in the current fugitive emissions control plan for control of fugitive emissions from COMG4 fugitive emission sources, if these sources become active. The Plan currently specifies that practices for fugitive dust control at a minimum shall include water spray (TREA34 and TREA37) at dust generation points (Railcar Material Loading (FUGI8) and Pellet Drop From Railcars into Dock Storage Bins (FUGI12), respectively) as specified in the Plan. [Minn. R. 7007.0800, subp. 2, Minn. R. 7011.0150]

COMG 6 CEMS & COMS

requirements Part 75 and SIP SO2 & NOx CEMS and COMS Requirements for STRU1 & STRU2 ‐ Requirements apply individually


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation to each CEMS and each COMS on each stack unless otherwise noted. PM and Hg CEMS requirements are located in COMG7.

5.5.1 Applicability. Minn. Rules 7017.1002 to 7017.1220 apply to owners and operators of emission facilities that are required by a compliance document, applicable requirement, or order of the commissioner to operate a CEMS or COMS except as listed in items A to C. A. If equivalent or more stringent requirements are mandated by a compliance document, applicable requirement, or order of the commissioner, those requirements supersede the corresponding requirements in parts 7017.1002 to 7017.1220. B. CEMS or COMS required by Code of Federal Regulations, title 40, part 75, which are only operated for the Acid Rain Program, Title IV of the Clean Air Act, are not subject to parts 7017.1002 to 7017.1220, except for the incorporation by reference of federal requirements in parts 7017.1010 to 7017.1020. C. CEMS required by Code of Federal Regulations, title 40, part 75, which are also required by a compliance document, applicable requirement, or order of the commissioner are not subject to parts 7017.1050 to 7017.1070, 7017.1170, and 7017.1180, subpart 1. Part 7017.1006 applies to any owner or operator of an emission facility. Parts 7017.1002 to 7017.1130 apply to both CEMS and COMS. Parts 7017.1135 to 7017.1180 apply to CEMS only. Parts 7017.1185 to 7017.1220 apply to COMS only. [Minn. R. 7017.1004, subp. 1]

5.5.2 The Continuous Emissions Monitoring System (CEMS) and Continuous Opacity Monitoring System (COMS) requirements listed below outline most of the requirements of 40 CFR pt. 75. However, additional monitoring requirements at 40 CFR pt. 75 may also apply to the facility, and it is the responsibility of the Permittee to meet all applicable requirements. [Minn. R. 7007.0800, subp. 4(A)]

5.5.3 Emissions Monitoring: The Permittee shall use CEMS to measure NOx, SO2, and CO2 emissions, a continuous monitor to measure diluent (CO2 or O2) concentration, a COMS to measure opacity, and a flow monitor to measure flow rate


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation from each stack (STRU1 and STRU2). [40 CFR 75.10(a), Minn. R. 7017.1006]

5.5.4 Continuous Operation: CEMS and 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 as described at Minn. R. 7017.1090, subp. 2. This requirement applies whether or not a numerical emission limit applies during these periods. A CEMS or COMS must not be bypassed except in emergencies where failure to bypass would endanger human health, safety, or plant equipment. [Minn. R. 7017.1090]

5.5.5 Certification Application: The Permittee shall apply for certification of each CEMS or COMS used under the Acid Rain Program. The Permittee shall submit the certification application in accordance with 40 CFR Section 75.60 and each complete certification application shall include the information specified in Section 75.63. [40 CFR 75.20(a)(2), 40 CFR 75.60(b), 40 CFR 75.63]

5.5.6 CEMS/COMS Certification Test: due 90 days after the first excess emissions report required for the CEMS/COMS. [Minn. R. 7017.1050, subp. 1]

5.5.7 The Permittee shall complete the following submittal and activity requirements for any Certification Test or Recertification Test (required in Sections 5 or 6 of this permit): Certification Test Plan due 30 days before Certification Test. Certification Test Pretest Meeting due 7 days before Certification Test. Certification Test Report ‐ Microfiche Copy due 105 days after Certification Test. Certification Test Report due 45 days after Certification Test. The Notification, Test Plan, and Test Report may be submitted in alternate format as allowed by Minn. R. 7017.1120, subp. 2. The Test Report content shall meet the requirements at Minn. R. 7017.1080, subp. 4. [Minn. R. 7017.1060, subp. 1‐3, Minn. R. 7017.1080, subp. 1‐4]

5.5.8 CEMS/COMS Recertification Test: due 90 days of completion of any change which invalidates the CEMS or COMS certification status. Change which invalidate the monitor's certification status are described in Minn. R. 7017.1050, subp. 2. [Minn. R. 7017.1050, subp. 5]

5.5.9 CEMS and COMS Recordkeeping: The Permittee shall maintain for each pt. 75 affected unit a file of all measurements, data, reports, and other information required by pt. 75 at the source in a form suitable for inspection for at least three (3) years from the date of each record. The file shall contain all information required by 40 CFR Section 75.57. [40 CFR 75.57]


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 5.5.10 Recordkeeping: The Permittee must retain records of all COMS

and 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]

5.5.11 CEMS Quarterly Reports: The Permittee shall electronically report the data and information in 40 CFR Section 75.64(a), (b), and (c) to the Administrator quarterly. Each electronic CEMS report must be submitted to the Administrator within 30 days following the end of each calendar quarter. [40 CFR 75.64]

5.5.12 The Permittee shall submit quarterly CEMS and COMS excess emissions and downtime reports to the agency no later than 30 days after the end of each calendar quarter, as required in section 6.1 of this permit. [Minn. R. 7017.1110, subp. 1‐2]

5.5.13 CEMS Quality Assurance/Quality Control (QA/QC): The Permittee shall operate, calibrate, and maintain each CEMS according to the requirements of Section 75.21(a)(1)‐(10) and the QA/QC procedures in 40 CFR pt. 75, Appendix B as amended. [40 CFR 75.21(a)]

5.5.14 Monitoring Data: All data points collected by a CEMS shall be used to calculate individual hourly emission averages unless another applicable requirement requires more frequent averaging. In order for an hour of data to be considered, it must contain the following minimum number of data points: A. four data points, equally spaced, if the emission unit operated during the entire hour; B. two data points, at least 15 minutes apart, during periods of monitor calibration or routine maintenance; C. one data point if the emission unit operated for 15 minutes or less during the hour. [Minn. R. 7017.1160, subp. 1‐2]

5.5.15 Monitoring Data: Hourly averages shall be computed using at least one data point in each fifteen minute quadrant of an hour, where the unit combusted fuel during that quadrant of an hour. Not withstanding this requirement, an hourly average may be computed from at least two data points separated by a minimum of 15 minutes (where the unit operates for more than one quadrant of an hour) if data is unavailable as a result of the performance of calibration, quality assurance, or preventive maintenance activities pursuant to 40 CFR Section 75.21 and appendix B of pt. 75, or backups of data from the data acquisition and handling system, or recertification, pursuant to Section 75.20. The Permittee shall use all valid measurements or data points collected during an hour to calculate the hourly averages. All data points collected during an hour shall be, to the extent practicable, evenly spaced over the hour. [40 CFR 75.10(d)(1)]

5.5.16 Relative Accuracy Test Audit (RATA) Notification: due 30 days before CEMS RATA (required in Section 6 of this permit). The


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation notification may be made by facsimile, mail, electronic mail, or hand‐delivered document. [Minn. R. 7017.1180, subp. 2]

5.5.17 Relative Accuracy Test Audit (RATA) Results Summary: due 30 days after end of each calendar quarter in which a RATA (required in Section 6 of this permit) was conducted. The RATA summary report must be submitted on a form approved by the commissioner. [Minn. R. 7017.1180, subp. 3]

5.5.18 COMS Quality Assurance/Quality Control (QA/QC): The Permittee shall operate, calibrate, and maintain each continuous opacity monitoring system (COMS) used under the Acid Rain Program according to the procedures specified for State Implementation Plans, pursuant to part 51, appendix M. [40 CFR 75.21(b)]

5.5.19 Quality Assurance (QA) Plan: Develop and implement a written QA plan for each COMS. Each plan shall be on site and available for inspection within 30 days after monitor certification, and shall be revised as needed in order to keep it up to date with the facility's current policies and procedures. The plan shall contain written procedures that describe in detail complete, step‐by‐step procedures and operations for each of the following activities in Minn. R. 7017.1210, subp. 1, items (A) through (F). [Minn. R. 7017.1210, subp. 1]

5.5.20 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 procedures in part 60, appendix B, Performance Specification 1, and appendix F, Procedure 3. National Institute of Standards and Technology calibrations shall be on site available for inspection. Other calibrations shall be submitted as required by Minn. R. 7017.1220. [Minn. R. 7007.0800, subp. 4(D), Minn. R. 7017.1210, subp. 4]

5.5.21 COMS Daily Calibration Drift Test: As required by 40 CFR pt. 60, Appendix B, Performance Specification 1 (referenced by Section 75.14(a)), the calibration drift shall be quantified and recorded at zero (low‐level) and upscale (high‐level) at least once daily according to the procedures listed in 40 CFR Section 60.13(d)(2) and pt. 60, Appendix B, Performance Specification 1. The zero and upscale calibration levels must be determined using the span value specified in the applicable requirement. If the applicable requirement does not specify a span value, a span value of 60, 70, or 80 percent opacity must be used unless an alternative span value is approved by the commissioner. 40 CFR pt. 60, Appendix F shall be used to determine out‐of‐control periods for COMS. [40 CFR 75.14(a), Minn. R. 7017.1210, subp. 2]

5.5.22 Monitoring Data: All COMS data must be reduced to six‐minute averages. A six‐minute average is valid only if it contains data from at least five minutes within the averaging period. COMS data shall be reduced according to Minn. R.


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 7017.1200, subp. 3. [Minn. R. 7017.1200, subp. 1‐3]

5.5.23 Monitoring Data: Each COMS shall complete a minimum of one cycle of sampling and analyzing for each successive 10‐second period and one cycle of data recording for each successive 6‐minute period. Reduce all opacity data to 6‐minute averages calculated in accordance with the provisions of part 51, appendix M. [40 CFR 75.10(d)(2)]

5.5.24 COMS Calibration Error Audit Results Summary: due 30 days after end of each calendar quarter in which the COMS calibration error audit (required in Section 6 of this permit) was completed. The results must be submitted on a form approved by the commissioner. [Minn. R. 7017.1220]

COMG 7 Mercury and

Air Toxics Requirements

Part 63, Subpart UUUUU Requirements ‐ REQUIREMENTS APPLY INDIVIDUALLY TO EACH COMG7 BOILER AND MONITOR AS APPLICABLE, UNLESS OTHERWISE NOTED.

5.6.1 The Permittee shall comply with the requirements from 40 CFR pt. 63, subp. UUUUU prescribed in this permit. For any revision(s) to subp. UUUUU requirement(s) not yet incorporated into this permit, the Permittee shall comply with the revised subp. UUUUU requirement(s) in place of such obsolete requirement(s) in this permit. The Permittee shall submit an application in accordance with the requirements of Minn. R. 7007.1150 through Minn. R. 7007.1500 as soon as practicable after any subp. UUUUU revision that renders any subp. UUUUU permit requirement obsolete, to incorporate appropriate changes to the subp. UUUUU requirements in the permit. [Minn. R. 7007.0800, subp. 2]

5.6.2 40 CFR PART 63, SUBPART UUUUU The Permittee is subject to 40 CFR pt. 63, subp. UUUUU because it owns and operates EQUI64 (boiler 1) and EQUI5 (boiler 2) which are coal‐fired electric utility steam generating units (EUSGU or EGU) as defined in Section 63.10042. [40 CFR 63.10042, 40 CFR 63.9981, Minn. R. 7011.0563]

5.6.3 EQUI5 and EQUI64 are part of the affected source under pt. 63, subp. UUUUU which is defined as the collection of all


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation existing coal‐fired EGUs, as defined in Section 63.10042. [40 CFR 63.9982(a)(1), Minn. R. 7011.0563]

5.6.4 EQUI5 and EQUI64 are existing EGUs because they weren't constructed or reconstructed after May 3, 2011. [40 CFR 63.9982(d), Minn. R. 7011.0563]

5.6.5 The Permittee shall comply with 40 CFR pt. 63, subp. UUUUU. [40 CFR 63.9984(b), Minn. R. 7011.0563]

5.6.6 The Permittee shall meet the notification requirements in Section 63.10030 according to the schedule in Section 63.10030 and in pt. 63, subp. A. Some of the notifications must be submitted before the Permittee is required to comply with the emission limits and work practice standards in pt. 63, subp. UUUUU. [40 CFR 63.9984(c), Minn. R. 7011.0563]

5.6.7 The Permittee shall demonstrate that compliance has been achieved, by conducting the required performance tests and other activities, no later than 180 days after April 16, 2015. The Permittee conducted the required tests and submitted a Notice of Compliance Status to EPA on October 13, 2015. [40 CFR 63.9984(f), Minn. R. 7011.0563]

5.6.8 EQUI5 and EQUI64 are coal‐fired EGUs in the subcategory of EGUs designed for coal with a heating value greater than or equal to 8,300 Btu/lb. [40 CFR 63.9990(a)(1), Minn. R. 7011.0563]

5.6.9 The Permittee shall at all times meet the following requirements: (i) Each emission limit and work practice standard in pt. 63, subp. UUUUU Tables 2 and 3, respectively, that applies to EQUI5 and EQUI64, except as provided under Section 63.10009, and (ii) Each operating limit in pt. 63, subp. UUUUU Table 4 that applies to EQUI5 and EQUI64. [40 CFR 63.9991(a), Minn. R. 7011.0563]

5.6.10 (b) As provided in Section 63.6(g), the Administrator may approve use of an alternative to the work practice standards in Section 63.9991. (c) The Permittee may use the alternate SO2 limit in Table 2 to pt. 63, subp. UUUUU (because EQUI64 is equipped with dry flue gas desulfurization technology (TREA28) and has EQUI43 (a SO2 continuous emissions monitoring system (CEMS) installed on the EQUI64 stack (STRU1), and because EQUI5 is equipped with dry flue gas desulfurization technology (TREA27) and has EQUI30 (a SO2 continuous emissions monitoring system (CEMS) installed on the EQUI5 stack (STRU2)), providing at all times the Permittee operates TREA27 and TREA28 consistent with Section 63.10000(b). [40 CFR 63.9991(b) & (c), Minn. R. 7011.0563]


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 5.6.11 The Permittee shall comply with the pt. 63, subp. UUUUU

emission limits and operating limits. These limits apply at all times except during periods of startup and shutdown; however, the Permittee is required to meet the work practice requirements in Table 3 of pt. 63, subp. UUUUU during periods of startup or shutdown. [40 CFR 63.10000(a), Minn. R. 7011.0563]

5.6.12 The Permittee shall limit Filterable Total Particulate Matter <= 0.03 pounds per million Btu heat input from EQUI5 and EQUI64 or, the Permittee shall limit Filterable Total Particulate Matter <= 0.30 pounds/megawatt‐hour from EQUI5 and EQUI64. In lieu of these filterable total PM limits, the Permittee may elect to limit Total non‐Hg HAP metals to <=5.0 E‐05 lb/MMBtu from EQUI5 and EQUI64, or <=0.5 lb/GWh from EQUI5 and EQUI64, OR, The Permittee may elect to limit individual HAP metals from EQUI5 and EQUI64 as follows: Antimony (Sb): <=8.0E‐1 lb/TBtu or <=8.0E‐3 lb/GWh Arsenic (As): <=1.1E0 lb/TBtu or <=2.0E‐2 lb/GWh Beryllium (Be): <=2.0E‐1 lb/TBtu or <=2.0E‐3 lb/GWh Cadmium (Cd): <=3.0E‐1 lb/TBtu or <=3.0E‐3 lb/GWh Chromium (Cr): <=2.8E0 lb/TBtu or <=3.0E‐2 lb/GWh Cobalt (Co): <=8.0E‐1 lb/TBtu or <=8.0E‐3 lb/GWh Lead (Pb): <=1.2E0 lb/TBtu or <=2.0E‐2 lb/GWh Manganese (Mn): <=4.0E0 lb/TBtu or <=5.0E‐2 lb/GWh Nickel (Ni): <=3.5E0 lb/TBtu or <=4.0E‐2 lb/GWh Selenium (Se): <=5.0E0 lb/TBtu or <=6.0E‐2 lb/GWh. [40 CFR pt. 63, subp. UUUUU, Table 2, Minn. R. 7011.0563]

5.6.13 The Permittee shall limit SO2 or HCl as follows: Sulfur Dioxide <= 0.20 pounds per million Btu heat input from EQUI5 and EQUI64 or <= 1.5 pounds/megawatt‐hour from EQUI5 and EQUI64; OR Hydrochloric Acid <= 0.002 pounds per million Btu from EQUI5 and EQUI64, or <= 0.02 pounds per megawatt‐hour from EQUI5 and EQUI64. [40 CFR pt. 63, subp. UUUUU, Table 2, Minn. R. 7011.0563]

5.6.14 The Permittee shall limit Mercury emissions to either of the following limits: Mercury <= 1.2 pounds per trillion Btu from EQUI5 and EQUI64, or Mercury <= 0.013 pound per gigawatt‐hour from EQUI5 and EQUI64. [40 CFR pt. 63, subp. UUUUU,


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation Table 2, Minn. R. 7007.0800, subp. 2, Minn. R. 7011.0563]

5.6.15 Work Practice Standards (pt. 63, subp. UUUUU Table 3). 1. The Permittee shall conduct a tune‐up of each EGU burner and combustion controls at least each 36 calendar months, or each 48 calendar months if neural network combustion optimization software is employed, as specified in Section 63.10021(e). 2. NA 3. A coal‐fired EGU during startup: The Permittee has the option of complying using either of the following work practice standards. (1) If the Permittee chooses to comply using paragraph (1) of the definition of "startup" in Section 63.10042, the Permittee must operate all CMS during startup. Startup means either the first‐ever firing of fuel in a boiler for the purpose of producing electricity, or the firing of fuel in a boiler after a shutdown event for any purpose. Startup ends when any of the steam from the boiler is used to generate electricity for sale over the grid or for any other purpose (including on site use). For startup of a unit, the Permittee must use clean fuels as defined in Section 63.10042 for ignition. Once the Permittee converts to firing coal the Permittee must engage all of the applicable control technologies except dry scrubber and SCR. The Permittee must start the dry scrubber and SCR systems, if present, appropriately to comply with relevant standards applicable during normal operation. The Permittee must comply with all applicable emissions limits at all times except for periods that meet the applicable definitions of startup and shutdown in pt. 63, subp. UUUUU. The Permittee must keep records during startup periods. The Permittee must provide reports concerning activities and startup periods, as specified in Section 63.10011(g) and Section 63.10021(h) and (i). (2) If the Permittee chooses to comply using paragraph (2) of the definition of "startup" in Section 63.10042, the Permittee must operate all CMS during startup. The Permittee must also collect appropriate data, and must calculate the pollutant emission rate for each hour of startup. For startup of an EGU, the Permittee must use one or a combination of the clean fuels defined in Section 63.10042 to the maximum extent possible throughout the startup period. The Permittee must have sufficient clean fuel capacity to engage and operate the PM control device within one hour of adding coal to the unit. The Permittee must meet the startup


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation period work practice requirements as identified in Section 63.10020(e). Once the Permittee starts firing coal, the Permittee must vent emissions to the main stack(s). the Permittee must comply with the applicable emission limits within 4 hours of start of electricity generation. The Permittee must engage and operate particulate matter control(s) within 1 hour of first firing of coal. The Permittee must start all other applicable control devices as expeditiously as possible, considering safety and manufacturer/supplier recommendations, but, in any case, when necessary to comply with other standards made applicable to the EGU by a permit limit or a rule other than pt. 63, subp. UUUUU that require operation of the control devices. If the Permittee chooses to use just one set of sorbent traps to demonstrate compliance with Hg emission limits, the Permittee must comply with all applicable Hg emission limits at all times; otherwise, the Permittee must comply with all applicable emission limits at all times except for startup or shutdown periods conforming to this practice. The Permittee must collect monitoring data during startup periods, as specified in Section 63.10020(a) and (e). The Permittee must keep records during startup periods, as provided in Sections 63.10032 and 63.10021(h). Any fraction of an hour in which startup occurs constitutes a full hour of startup. The Permittee must provide reports concerning activities and startup periods, as specified in Sections 63.10011(g), 63.10021(i), and 63.10031. [40 CFR pt. 63, subp. UUUUU, Table 3, Minn. R. 7011.0563]

5.6.16 Work Practice Standards (cont.). 4. A coal‐fired EGU during shutdown The Permittee must operate all CMS during shutdown. The Permittee must also collect appropriate data, and you must calculate the pollutant emission rate for each hour of shutdown. While firing coal during shutdown, the Permittee must vent emissions to the main stack(s) and operate all applicable control devices and continue to operate those control devices after the cessation of coal being fed into the EGU and for as long as possible thereafter considering operational and safety concerns. In any case, the Permittee must operate controls when necessary to comply with other standards made applicable to the EGU by a permit limit or a rule other than pt. 63, subp. UUUUU and that require operation of the control


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation devices. If, in addition to the fuel used prior to initiation of shutdown, another fuel must be used to support the shutdown process, that additional fuel must be one or a combination of the clean fuels defined in Section 63.10042 and must be used to the maximum extent possible. The Permittee must comply with all applicable emission limits at all times except during startup periods and shutdown periods at which time the Permittee must meet this work practice. The Permittee must collect monitoring data during shutdown periods, as specified in Section 63.10020(a). The Permittee must keep records during shutdown periods, as provided in Sections 63.10032 and 63.10021(h). Any fraction of an hour in which shutdown occurs constitutes a full hour of shutdown. The Permittee must provide reports concerning activities and shutdown periods, as specified in Sections 63.10011(g), 63.10021(i), and 63.10031. [40 CFR pt. 63, subp. UUUUU Table 3, Minn. R. 7011.0563]

5.6.17 At all times the Permittee shall operate and maintain EQUI5 and EQUI64, including associated air pollution control equipment and monitoring equipment, in a manner consistent with safety and good air pollution control practices for minimizing emissions. Determination of whether such operation and maintenance procedures are being used will be based on information available to the EPA Administrator which may include, but is not limited to, monitoring results, review of operation and maintenance procedures, review of operation and maintenance records, and inspection of the source. [40 CFR 63.10000(b), Minn. R. 7011.0563]

5.6.18 Initial performance testing is required for all pollutants to demonstrate compliance with the applicable emission limits. [40 CFR 63.10000(c)(1), Minn. R. 7011.0563]

5.6.19 The Permittee may conduct the initial performance testing in accordance with Section 63.10005(h), to determine whether EQUI5 and/or EQUI64 qualify as a low emitting EGU (LEE) for one or more applicable emissions limits. [40 CFR 63.10000(c)(1)(i), Minn. R. 7011.0563]

5.6.20 For EQUI5 and/or EQUI64 to continue qualifying as an LEE for Hg emissions limits, the Permittee shall conduct a 30‐day performance test using Method 30B at least once every 12 calendar months to demonstrate continued LEE status. [40 CFR 63.10000(c)(1)(ii), Minn. R. 7011.0563]

5.6.21 For EQUI5 and/or EQUI64 to continue qualifying as an LEE for any other applicable emissions limits, the Permittee must conduct a performance test at least once every 36 calendar months to demonstrate continued LEE status. [40 CFR 63.10000(c)(1)(iii), Minn. R. 7011.0563]


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 5.6.22 If EQUI5 and/or EQUI64 does not qualify as a LEE for total non‐

mercury HAP metals, individual non‐mercury HAP metals, or filterable particulate matter (PM), the Permittee must demonstrate compliance through an initial performance test and must monitor continuous performance through either use of a particulate matter continuous parametric monitoring system (PM CPMS), a PM CEMS, or, compliance performance testing repeated quarterly. (Note: The Permittee has installed PM CEMS EQUI95 and EQUI96, on Unit 1 (EQUI64) and Unit 2 (EQUI5), respectively). [40 CFR 63.10000(c)(1)(iv), Minn. R. 7011.0563]

5.6.23 If EQUI5 and/or EQUI64 does not qualify as a LEE for hydrogen chloride (HCl), the Permittee may demonstrate initial and continuous compliance through use of an HCl CEMS, installed and operated in accordance with Appendix B to pt. 63, subp. UUUUU. As an alternative to HCl CEMS, the Permittee may demonstrate initial and continuous compliance by conducting an initial and periodic quarterly performance stack test for HCl. [40 CFR 63.10000(c)(1)(v), Minn. R. 7011.0563]

5.6.24 If EQUI5 and/or EQUI64 does not qualify as a LEE for Hg, the Permittee must demonstrate initial and continuous compliance through use of a Hg CEMS or a sorbent trap monitoring system, in accordance with Appendix A of pt. 63, subp. UUUU. (A) The Permittee may choose to use separate sorbent trap monitoring systems to comply with pt. 63, subp. 63: One sorbent trap monitoring system to demonstrate compliance with the numeric mercury emissions limit during periods other than startup or shutdown and the other sorbent trap monitoring system to report average mercury concentration during startup periods or shutdown periods. (B) The Permittee may choose to use one sorbent trap monitoring system to demonstrate compliance with the mercury emissions limit at all times (including startup periods and shutdown periods) and to report average mercury concentration. The Permittee must follow the startup or shutdown requirements that follow and as given in Table 3 to pt. 63, subp. UUUUU for EQUI64. (Note: The Permittee has installed sorbent traps EQUI97 and EQUI98, on Unit 1 (EQUI64) and Unit 2 (EQUI5), respectively). [40 CFR 63.10000(c)(1)(vi), Minn. R. 7011.0563]

5.6.25 If the Permittee demonstrates compliance with any applicable emissions limit through use of a continuous monitoring system (CMS), where a CMS includes a continuous parameter monitoring system (CPMS) as well as a continuous emissions monitoring system (CEMS), the Permittee must develop a site‐


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation specific monitoring plan and submit this site‐specific monitoring plan, if requested, at least 60 days before the initial performance evaluation (where applicable) of the CMS. This requirement also applies if the Permittee petitions the Administrator for alternative monitoring parameters under Section 63.8(f). This requirement to develop and submit a site‐specific monitoring plan does not apply to affected sources with existing monitoring plans that apply to CEMS and CPMS prepared under Appendix B to pts. 60 or 75, and that meet the requirements of Section 63.10010. Using the process described in Section 63.8(f)(4), the Permittee may request approval of monitoring system quality assurance and quality control procedures alternative to those specified in this paragraph of Section 63.10000 and, if approved, include those in the Permittee's site‐specific monitoring plan. The monitoring plan must address the provisions in paragraphs 63.1000(d)(2) through (5). [40 CFR 63.10000(d)(1), Minn. R. 7011.0563]

5.6.26 The site‐specific monitoring plan shall include the information specified in paragraphs 63.10000(d)(5)(i) through (d)(5)(vii). Alternatively, the requirements of paragraphs 63.10000(d)(5)(i) through (d)(5)(vii) are considered to be met for a particular CMS or sorbent trap monitoring system if: (i) The CMS or sorbent trap monitoring system is installed, certified, maintained, operated, and quality‐assured either according to pt., or Appendix A or B to pt. 63, subp. UUUUU; and (ii) The recordkeeping and reporting requirements of pt. 75, or Appendix A or B to pt. 63, subp. UUUUU that pertain to the CMS are met. [40 CFR 63.10000(d)(2), Minn. R. 7011.0563]

5.6.27 (3) If requested by the Administrator, the Permittee must submit the monitoring plan (or relevant portion of the plan) at least 60 days before the initial performance evaluation of a particular CMS, except where the CMS has already undergone a performance evaluation that meets the requirements of Section 63.10010 (e.g., if the CMS was previously certified under another program). (4) The Permittee must operate and maintain the CMS according to the site‐specific monitoring plan. [40 CFR 63.10000(d)(3) & (4), Minn. R. 7011.0563]

5.6.28 The provisions of the site‐specific monitoring plan must address the following items: (i) Installation of the CMS or sorbent trap monitoring system sampling probe or other interface at a measurement location relative to EQUI64 such that the measurement is representative of control of the exhaust emissions (e.g., on or downstream of the last control device). See Section 63.10010(a) for further details. For PM CPMS installations,


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation follow the procedures in Section 63.10010(h). (ii) Performance and equipment specifications for the sample interface, the pollutant concentration or parametric signal analyzer, and the data collection and reduction systems. (iii) Schedule for conducting initial and periodic performance evaluations. (iv) Performance evaluation procedures and acceptance criteria (e.g., calibrations), including the quality control program in accordance with the general requirements of Section 63.8(d). (v) On‐going operation and maintenance procedures, in accordance with the general requirements of Sections 63.8(c)(1)(ii), (c)(3), and (c)(4)(ii). (vi) Conditions that define a CMS that is out of control consistent with Section 63.8(c)(7)(i) and for responding to out of control periods consistent with Sections 63.8(c)(7)(ii) and (c)(8). (vii) On‐going recordkeeping and reporting procedures, in accordance with the general requirements of Sections 63.10(c), (e)(1), and (e)(2)(i), or as specifically required under subp. UUUUU. [40 CFR 63.10000(d)(5), Minn. R. 7011.0563]

5.6.29 The Permittee must perform periodic tune‐ups of EQUI5 and EQUI64, according to Section 63.10021(e), as part of showing continuous compliance. [40 CFR 63.10000(e), Minn. R. 7011.0563]

5.6.30 The Permittee is subject to the requirements of pt. 63, subp. UUUUU for at least 6 months following the last date EQUI5 or EQUI64 met the definition of an EGU subject to subp. UUUUU (e.g., 6 months after a cogeneration unit provided more than one third of its potential electrical output capacity and more than 25 megawatts electrical output to any power distribution system for sale). The Permittee may opt to remain subject to the provisions of subp. UUUUU beyond 6 months after the last date EQUI5 or EQUI64 met the definition of an EGU subject to subp. UUUUU, unless EQUI5 or EQUI64 is a solid waste incineration unit subject to standards under CAA section 129 (e.g., 40 CFR Part 60, Subpart CCCC (New Source Performance Standards (NSPS) for Commercial and Industrial Solid Waste Incineration Units, or Subpart DDDD (Emissions Guidelines (EG) for Existing Commercial and Industrial Solid Waste Incineration Units). Notwithstanding the provisions of subp. UUUUU, an EGU that starts combusting solid waste is immediately subject to standards under CAA section 129 and the EGU remains


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation subject to those standards until the EGU no longer meets the definition of a solid waste incineration unit consistent with the provisions of the applicable CAA section 129 standards. [40 CFR 63.10000(f), Minn. R. 7011.0563]

5.6.31 If EQUI5 or EQUI64 no longer meets the definition of an EGU subject to subp. UUUUU the Permittee must be in compliance with any newly applicable standards on the date EQUI5 or EQUI64 is no longer subject to subp. UUUUU. The date EQUI5 or EQUI64 is no longer subject to subp. UUUUU is a date selected by the Permittee, that must be at least 6 months from the date that EQUI5 or EQUI64 last met the definition of an EGU subject to subp. UUUUU or the date EQUI5 or EQUI64 begins combusting solid waste, consistent with Section 63.9983(d). EQUI5 and EQUI64 must remain in compliance with this subp. UUUUU until the date the Permittee selects to cease complying with subp. UUUUU or the date EQUI5 or EQUI64 begins combusting solid waste, whichever is earlier. [40 CFR 63.10000(g), Minn. R. 7011.0563]

5.6.32 (1) If the Permittee owns or operates an EGU that does not meet the definition of an EGU subject to subp. UUUUU on April 16, 2015, and the Permittee commences or recommences operations that cause the EGU to meet the definition of an EGU subject to subp. UUUUU, the Permittee is to the provisions of subp. UUUUU, including, but not limited to, the emission limitations and the monitoring requirements, as of the first day the EGU meets the definition of an EGU subject to subp. UUUUU. The Permittee must complete all initial compliance demonstrations for subp. UUUUU applicable to the EGU within 180 days after commencing or recommencing operations that cause the EGU to meet the definition of an EGU subject to subp. UUUUU. (2) The Permittee must provide 30 days prior notice of the date it intends to commence or recommence operations that cause the EGU to meet the definition of an EGU subject to subp. UUUUU. The notification must identify: (i) The name of the owner or operator of the EGU, the location of the facility, the unit(s) that will commence or recommence operations that will cause the unit(s) to meet the definition of an EGU subject to subp. UUUUU, and the date of the notice; (ii) The 40 CFR part 60, part 62, or part 63 subpart and subcategory currently applicable to the EGU, and the subcategory of subp. UUUUU that will be applicable after commencing or recommencing operation that will cause the EGU to meet the definition of an EGU subject to subp. UUUUU; (iii) The date on which the EGU became subject to the


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation currently applicable emission limits; (iv) The date upon which it commences or recommences operations that will cause the EGU to meet the definition of an EGU subject to subp. UUUUU, consistent with 40 CFR 63.10000(f). [40 CFR 63.10000(h), Minn. R. 7011.0563]

5.6.33 (1) If the Permittee owns or operates an EGU subject to subp. UUUUU, and it has been at least 6 months since the EGU was operated in a manner that caused the EGU to meet the definition of an EGU subject to subp. UUUUU, the Permittee may, consistent with Section 63.10000(g), select the date on which the EGU will no longer be subject to subp. UUUUU. The Permittee must be in compliance with any newly applicable section 112 or 129 standards on the date selected by the Permittee. (2) The Permittee must provide 30 days prior notice of the date the EGU will cease complying with subp. UUUUU. The notification must identify: (i) The name of the owner or operator of the EGU(s), the location of the facility, the EGU(s) that will cease complying with subp. UUUUU, and the date of the notice; (ii) The currently applicable subcategory under pt.. 63, subp. UUUUU, and any 40 CFR part 60, part 62, or part 63 subpart and subcategory that will be applicable after the Permittee ceases complying with subp. UUUUU; (iii) The date on which the Permittee became subject to subp. UUUUU; (iv) The date upon which the Permittee will cease complying with subp. UUUUU, consistent with Section 63.10000(g). [40 CFR 63.10000(i), Minn. R. 7011.0563]

5.6.34 All air pollution control equipment necessary for compliance with any newly applicable emissions limits which apply as a result of the cessation or commencement or recommencement of operations that cause the Permittee's EGU to meet the definition of an EGU subject to subp. UUUUU must be installed and operational as of the date the Permittee's source ceases to be or becomes subject to subp. UUUUU. [40 CFR 63.10000(j), Minn. R. 7011.0563]

5.6.35 All monitoring systems necessary for compliance with any newly applicable monitoring requirements which apply as a result of the cessation or commencement or recommencement of operations that cause the Permittee's EGU to meet the definition of an EGU subject to subp. UUUUU must be installed and operational as of the date the


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation Permittee's EGU ceases to be or becomes subject to subp. UUUUU. All calibration and drift checks must be performed as of the date the EGU ceases to be or becomes subject to subp. UUUUU. The Permittee must also comply with provisions of Sections 63.10010, 63.10020, and 63.10021 of subp. UUUUU. Relative accuracy tests must be performed as of the performance test deadline for PM CEMS, if applicable. Relative accuracy testing for other CEMS need not be repeated if that testing was previously performed consistent with CAA section 112 monitoring requirements or monitoring requirements under subp. UUUUU. [40 CFR 63.10000(k), Minn. R. 7011.0563]

5.6.36 On or before the date an EGU is subject to subp. UUUUU, the Permittee must install, certify, operate, maintain, and quality assure each monitoring system necessary for demonstrating compliance with the work practice standards for PM or non‐mercury HAP metals during startup periods and shutdown periods. The Permittee must collect, record, report, and maintain data obtained from these monitoring systems during startup periods and shutdown periods. [40 CFR 63.10000(l), Minn. R. 7011.0563]

5.6.37 In response to an action to enforce the standards set forth in Section 63.9991, the Permittee may assert an affirmative defense to a claim for civil penalties for exceedances of such standards that are caused by malfunction, as defined at 40 CFR 63.2. Appropriate penalties may be assessed, however, if the Permittee fails to meet its burden of proving all of the requirements in the affirmative defense. The affirmative defense shall not be available for claims for injunctive relief. (a) To establish the affirmative defense in any action to enforce such a limit, the Permittee must timely meet the notification requirements in Section 63.10001(b), and must prove by a preponderance of evidence that: (1) The excess emissions: (i) Were caused by a sudden, infrequent, and unavoidable failure of air pollution control and monitoring equipment, process equipment, or a process to operate in a normal or usual manner, and (ii) Could not have been prevented through careful planning, proper design or better operation and maintenance practices; and (iii) Did not stem from any activity or event that could have been foreseen and avoided, or planned for; and (iv) Were not part of a recurring pattern indicative of


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation inadequate design, operation, or maintenance; and (2) Repairs were made as expeditiously as possible when the applicable emission limitations were being exceeded. Off‐shift and overtime labor were used, to the extent practicable to make these repairs; and (3) The frequency, amount and duration of the excess emissions (including any bypass) were minimized to the maximum extent practicable during periods of such emissions; and (4) If the excess emissions resulted from a bypass of control equipment or a process, then the bypass was unavoidable to prevent loss of life, personal injury, or severe property damage; and (5) All possible steps were taken to minimize the impact of the excess emissions on ambient air quality, the environment and human health; and (6) All emissions monitoring and control systems were kept in operation if at all possible, consistent with safety and good air pollution control practices; and (7) All of the actions in response to the excess emissions were documented by properly signed, contemporaneous operating logs; and (8) At all times, the affected source was operated in a manner consistent with good practices for minimizing emissions; and (9) A written root cause analysis has been prepared, the purpose of which is to determine, correct, and eliminate the primary causes of the malfunction and the excess emissions resulting from the malfunction event at issue. The analysis shall also specify, using best monitoring methods and engineering judgment, the amount of excess emissions that were the result of the malfunction. [40 CFR 63.10001(a), Minn. R. 7011.0563]

5.6.38 Notification. The Permittee of the affected source experiencing an exceedance of its emission limit(s) during a malfunction shall notify the Administrator by telephone or facsimile (FAX) transmission as soon as possible, but no later than two business days after the initial occurrence of the malfunction or, if it is not possible to determine within two business days whether the malfunction caused or contributed to an exceedance, no later than two business days after the Permittee knew or should have known that the malfunction


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation caused or contributed to an exceedance, but, in no event later than two business days after the end of the averaging period, if the Permittee wishes to avail itself of an affirmative defense to civil penalties for that malfunction. The Permittee seeking to assert an affirmative defense shall also submit a written report to the Administrator within 45 days of the initial occurrence of the exceedance of the standard in Section 63.9991 to demonstrate, with all necessary supporting documentation, that it has met the requirements set forth in Section 63.10001(a). The Permittee may seek an extension of this deadline for up to 30 additional days by submitting a written request to the Administrator before the expiration of the 45 day period. Until a request for an extension has been approved by the Administrator, the Permittee is subject to the requirement to submit such report within 45 days of the initial occurrence of the exceedance. [40 CFR 63.10001(b), Minn. R. 7011.0563]

5.6.39 General requirements. For EQUI5 and EQUI64, the Permittee must demonstrate initial compliance with each applicable emissions limit in Table 2 of subp. UUUUU through performance testing. Where two emissions limits are specified for a particular pollutant (e.g., a heat input‐based limit in lb/MMBtu and an electrical output‐based limit in lb/MWh), the Permittee may demonstrate compliance with either emission limit. For a particular compliance demonstration, the Permittee may be required to conduct one or more of the following activities in conjunction with performance testing: collection of hourly electrical load data (megawatts); establishment of operating limits according to Section 63.10011 and Table 7 to subp. UUUUU; and CMS performance evaluations. In all cases, the Permittee must demonstrate initial compliance no later than the applicable date in Section 63.10005(f) for tune‐up work practices for existing EGUs, and in Section 63.9984 for other requirements for existing EGUs. [40 CFR 63.10005(a), Minn. R. 7011.0563]

5.6.40 To demonstrate initial compliance with an applicable emissions limit in Table 2 to subp. UUUUU using stack testing, the initial performance test generally consists of three runs at specified process operating conditions using approved methods. If the Permittee is required to establish operating limits (see Section 63.10005(d) and Table 4 to subp. UUUUU), the Permittee must collect all applicable parametric data during the performance test period. Also, if Permittee chooses to comply with an electrical output‐based emission limit, Permittee must collect hourly electrical load data during the test period. [40 CFR 63.10005(a)(1), Minn. R. 7011.0563]

5.6.41 To demonstrate initial compliance using either a CMS that measures HAP concentrations directly (i.e., an Hg, HCl, or HF CEMS, or a sorbent trap monitoring system) or an SO2 or PM


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation CEMS, the initial performance test consists of 30‐ (or, if emissions averaging for Hg is used, 90‐) boiler operating days of data collected by the initial compliance demonstration date specified in Section 63.9984(f) with the certified monitoring system. Pollutant emission rates measured during startup periods and shutdown period (as defined in Section 63.10042) are not to be included in the compliance demonstration, except as otherwise provided in Section 63.10000(c)(1)(vi)(B) and Section 63.1005(a)(2)(iii). (i) The 30‐ (or, if applicable, 90‐) boiler operating day CMS performance test must demonstrate compliance with the applicable Hg, HCl, HF, PM, or SO2 emissions limit in Table 2 to subp. UUUUU. (ii) The Permittee must collect hourly data from auxiliary monitoring systems (i.e., stack gas flow rate, CO2, O2, or moisture, as applicable) during the performance test period, in order to convert the pollutant concentrations to units of the standard. If the Permittee chooses to comply with an electrical output‐based emission limit, the Permittee must also collect hourly electrical load data during the performance test period. [40 CFR 63.10005(a)(2), Minn. R. 7011.0563]

5.6.42 Performance testing requirements. If the Permittee chooses to use performance testing to demonstrate initial compliance with the applicable emissions limits in Table 2 to subp. UUUUU for its EGUs, the Permittee must conduct the tests according to Section 63.10007 and Table 5 to subp. UUUUU. For the purposes of the initial compliance demonstration, the Permittee may use test data and results from a performance test conducted prior to the date on which compliance is required as specified in Section 63.9984, provided that the following conditions are fully met: (1) For a performance test based on stack test data, the test was conducted no more than 12 calendar months prior to the date on which compliance is required as specified in Section 63.9984; (2) For a performance test based on data from a certified CEMS or sorbent trap monitoring system, the test consists of all valid CMS data recorded in the 30 boiler operating days immediately preceding that date; (3) The performance test was conducted in accordance with all applicable requirements in Section 63.10007 and Table 5 to subp. UUUUU; (4) A record of all parameters needed to convert pollutant


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation concentrations to units of the emission standard (e.g., stack flow rate, diluent gas concentrations, hourly electrical loads) is available for the entire performance test period; and (5) For each performance test based on stack test data, the Permittee certifies, and keeps documentation demonstrating, that the EGU configuration, control devices, and fuel(s) have remained consistent with conditions since the prior performance test was conducted. [40 CFR 63.10005(b), Minn. R. 7011.0563]

5.6.43 CMS requirements. If, for a particular emission or operating limit, the Permittee is required to (or elects to) demonstrate initial compliance using a continuous monitoring system, the CMS must pass a performance evaluation prior to the initial compliance demonstration. If a CMS has been previously certified under another state or federal program and is continuing to meet the on‐going quality‐assurance (QA) requirements of that program, then, provided that the certification and QA provisions of that program meet the applicable requirements of Sections 63.10010(b) through (h), an additional performance evaluation of the CMS is not required under subp. UUUUU. (1) For an affected coal‐fired, the Permittee may demonstrate initial compliance with the applicable SO2, HCl, or HF emissions limit in Table 2 to subp. UUUUU through use of an SO2, HCl, or HF CEMS installed and operated in accordance with part 75 of this chapter or appendix B to subp. UUUUU, as applicable. The Permittee may also demonstrate compliance with a filterable PM emission limit in Table 2 to subp. UUUUU through use of a PM CEMS installed, certified, and operated in accordance with Section 63.10010(i). Initial compliance is achieved if the arithmetic average of 30‐boiler operating days of quality‐assured CEMS data, expressed in units of the standard (see Section 63.10007(e)), meets the applicable SO2, PM, HCl, or HF emissions limit in Table 2 to subp. UUUUU Use Equation 19‐19 of Method 19 in appendix A‐7 to part 60 of this chapter to calculate the 30‐boiler operating day average emissions rate. (Note: For this calculation, the term Ehj in Equation 19‐19 must be in the same units of measure as the applicable HCl or HF emission limit in Table 2 to subp. UUUUU). [40 CFR 63.10005(d), Minn. R. 7011.0563]

5.6.44 Tune‐ups. All affected EGUs are subject to the work practice standards in Table 3 of subp. UUUUU. As part of the Permittee's initial compliance demonstration, the Permittee must conduct a performance tune‐up of the EGU according to Section 63.10021(e). [40 CFR 63.10005(e), Minn. R. 7011.0563]

5.6.45 For existing affected sources a tune‐up may occur prior to April 16, 2012, so that existing sources without neural networks


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation have up to 42 calendar months (3 years from promulgation plus 180 days) or, in the case of units employing neural network combustion controls, up to 54 calendar months (48 months from promulgation plus 180 days) after the date that is specified for the Permittee's source in Section 63.9984 and according to the applicable provisions in Section 63.7(a)(2) as cited in Table 9 to subp. UUUUU to demonstrate compliance with this requirement. If a tune‐up occurs prior to such date, the source must maintain adequate records to show that the tune‐up met the requirements of this standard. [40 CFR 63.10005(f), Minn. R. 7011.0563]

5.6.46 Low emitting EGUs. The provisions of Section 63.10005(h) apply to pollutants with emissions limits from existing EGUs. The Permittee may not pursue this compliance option if its existing EGU is equipped with an acid gas scrubber and has a main stack and bypass stack exhaust configuration. (1) An EGU may qualify for low emitting EGU (LEE) status for Hg, HCl, HF, filterable PM, total non‐Hg HAP metals, or individual non‐Hg HAP metals (or total HAP metals or individual HAP metals, for liquid oil‐fired EGUs) if the Permittee collects performance test data that meet the requirements of Section 63.10005(h), and if those data demonstrate: (i) For all pollutants except Hg, performance test emissions results less than 50 percent of the applicable emissions limits in Table 2 to subp. UUUUU for all required testing for 3 consecutive years; or (ii) For Hg emissions from an existing EGU, either: (A) Average emissions less than 10 percent of the applicable Hg emissions limit in Table 2 to subp. UUUUU (expressed either in units of lb/TBtu or lb/GWh); or (B) Potential Hg mass emissions of 29.0 or fewer pounds per year and compliance with the applicable Hg emission limit in Table 2 to subp. UUUUU (expressed either in units of lb/TBtu or lb/GWh). [40 CFR 63.10005(h)(1), Minn. R. 7011.0563]

5.6.47 (2) For all pollutants except Hg, the Permittee must conduct all required performance tests described in Section 63.10007 to demonstrate that a unit qualifies for LEE status. (i) When conducting emissions testing to demonstrate LEE status, the Permittee must increase the minimum sample volume specified in Table 2 nominally by a factor of two. (ii) Follow the instructions in Section 63.10007(e) and Table 5


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation to subp. UUUUU to convert the test data to the units of the applicable standard. [40 CFR 63.10005(h)(2), Minn. R. 7011.0563]

5.6.48 (3) For Hg, the Permittee must conduct a 30‐boiler operating day performance test using Method 30B in appendix A‐8 to part 60 of this chapter to determine whether a unit qualifies for LEE status. Locate the Method 30B sampling probe tip at a point within the 10 percent centroidal area of the duct at a location that meets Method 1 in appendix A‐1 to part 60 of this chapter and conduct at least three nominally equal length test runs over the 30‐boiler operating day test period. Collect Hg emissions data continuously over the entire test period (except when changing sorbent traps or performing required reference method QA procedures), under all process operating conditions. The Permittee may use a pair of sorbent traps to sample the stack gas for no more than 10 days. (i) Depending on whether the Permittee intends to assess LEE status for Hg in terms of the lb/TBtu or lb/GWh emission limit in Table 2 to subp. UUUUU or in terms of the annual Hg mass emissions limit of 29.0 lb/year, the Permittee will have to collect some or all of the following data during the 30‐boiler operating day test period (see paragraph (h)(3)(iii) of this section): (A) Diluent gas (CO2 or O2) data, using either Method 3A in appendix A‐3 to part 60 of this chapter or a diluent gas monitor that has been certified according to part 75 of this chapter. (B) Stack gas flow rate data, using either Method 2, 2F, or 2G in appendices A‐1 and A‐2 to part 60 of this chapter, or a flow rate monitor that has been certified according to part 75 of this chapter. (C) Stack gas moisture content data, using either Method 4 in appendix A‐1 to part 60 of this chapter, or a moisture monitoring system that has been certified according to part 75 of this chapter. (D) Hourly electrical load data (megawatts), from facility records. [40 CFR 63.10005(h)(3)(i), Minn. R. 7011.0563]

5.6.49 If the Permittee uses CEMS to measure CO2 (or O2) concentration, and/or flow rate, and/or moisture, record hourly average values of each parameter throughout the 30‐boiler operating day test period. If the Permittee opts to use EPA reference methods rather than CEMS for any parameter, the Permittee must perform at least one representative test run on each operating day of the test period, using the


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation applicable reference method. [40 CFR 63.10005(h)(3)(ii), Minn. R. 7011.0563]

5.6.50 (iii) Calculate the average Hg concentration, in micrograms/m3 (dry basis), for the 30‐boiler operating day performance test, as the arithmetic average of all Method 30B sorbent trap results. Also calculate, as applicable, the average values of CO2 or O2 concentration, stack gas flow rate, stack gas moisture content, and electrical load for the test period. Then: (A) To express the test results in units of lb/TBtu, follow the procedures in Section 63.10007(e). Use the average Hg concentration and diluent gas values in the calculations. (B) To express the test results in units of lb/GWh, use Equations A‐3 and A‐4 in section 6.2.2 of appendix A to subp. UUUUU, replacing the hourly values "Ch", "Qh", "Bws" and "(MW)h" with the average values of these parameters from the performance test. [40 CFR 63.10005(h)(3)(iii)(A) & (B), Minn. R. 7011.0563]

5.6.51 (C) To calculate pounds of Hg per year, use one of the following methods: (1) Multiply the average lb/TBtu Hg emission rate (determined according to Section 63.10005(h)(3)(iii)(A)) by the maximum potential annual heat input to the unit (TBtu), which is equal to the maximum rated unit heat input (TBtu/hr) times 8,760 hours. If the maximum rated heat input value is expressed in units of MMBtu/hr, multiply it by 10^‐6 to convert it to TBtu/hr; or (2) Multiply the average lb/GWh Hg emission rate (determined according to Section 63.10005(h)(3)(iii)(B)) by the maximum potential annual electricity generation (GWh), which is equal to the maximum rated electrical output of the unit (GW) times 8,760 hours. If the maximum rated electrical output value is expressed in units of MW, multiply it by 10^‐3 to convert it to GW; or (3) If an EGU has a federally‐enforceable permit limit on either the annual heat input or the number of annual operating hours, the Permittee may modify the calculations in Section 63.10005(h)(3)(iii)(C)(1) by replacing the maximum potential annual heat input or 8,760 unit operating hours with the permit limit on annual heat input or operating hours (as applicable). [40 CFR 63.10005(h)(3)(iii)(C), Minn. R. 7011.0563]

5.6.52 Startup and shutdown for coal‐fired units. The Permittee must follow the requirements given in Table 3 to subp. UUUUU. [40 CFR 63.10005(j), Minn. R. 7011.0563]

5.6.53 The Permittee must submit a Notification of Compliance Status


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation summarizing the results of its initial compliance demonstration, as provided in Section 63.10030. [40 CFR 63.10005(k), Minn. R. 7011.0563]

5.6.54 For affected units meeting the LEE requirements of Section 63.10005(h), the Permittee must repeat the performance test once every 3 years (once every year for Hg) according to Table 5 to subp. UUUUU and Section 63.10007. Should subsequent emissions testing results show the unit does not meet the LEE eligibility requirements, LEE status is lost. If this should occur: (1) For all pollutant emission limits except for Hg, the Permittee must conduct emissions testing quarterly, except as otherwise provided in Section 63.10021(d)(1). (2) For Hg, the Permittee must install, certify, maintain, and operate a Hg CEMS or a sorbent trap monitoring system in accordance with appendix A to subp. UUUUU, within 6 calendar months of losing LEE eligibility. Until the Hg CEMS or sorbent trap monitoring system is installed, certified, and operating, the Permittee must conduct Hg emissions testing quarterly, except as otherwise provided in Section 63.10021(d)(1). The Permittee must have 3 calendar years of testing and CEMS or sorbent trap monitoring system data that satisfy the LEE emissions criteria to reestablish LEE status. [40 CFR 63.10006(b), Minn. R. 7011.0563]

5.6.55 Except where Sections 63.10006(a) or (b) apply, or where the Permittee installs, certifies, and operates a PM CEMS to demonstrate compliance with a filterable PM emissions limit, for coal‐fired EGUs you must conduct all applicable periodic emissions tests for filterable PM, individual, or total HAP metals emissions according to Table 5 to subp. UUUUU, Section 63.10007, and Section 63.10000(c), except as otherwise provided in Section 63.10021(d)(1). [40 CFR 63.10006(c), Minn. R. 7011.0563]

5.6.56 Except where Section 63.10006(b) applies, for coal‐fired EGUs that do not use either an HCl CEMS to monitor compliance with the HCl limit or an SO2 CEMS to monitor compliance with the alternate equivalent SO2 emission limit, the Permittee must conduct all applicable periodic HCl emissions tests according to Table 5 to subp. UUUUU and Section 63.10007 at least quarterly, except as otherwise provided in Section 63.10021(d)(1). [40 CFR 63.10006(d), Minn. R. 7011.0563]

5.6.57 Unless the Permittee follows the requirements listed in Section 63.10006(g) and (h), performance tests required at least every 3 calendar years must be completed within 35 to 37 calendar months after the previous performance test; performance tests required at least every year must be completed within 11 to 13 calendar months after the previous performance test; and performance tests required at least quarterly must be


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation completed within 80 to 100 calendar days after the previous performance test, except as otherwise provided in Section 63.10021(d)(1). [40 CFR 63.10006(f), Minn. R. 7011.0563]

5.6.58 If the Permittee elects to demonstrate compliance using emissions averaging under Section 63.10009, the Permittee must continue to conduct performance stack tests at the appropriate frequency given in Section 63.10006(c) through (f). [40 CFR 63.10006(g), Minn. R. 7011.0563]

5.6.59 If a performance test on a non‐mercury LEE shows emissions in excess of 50 percent of the emission limit and if the Permittee chooses to reapply for LEE status, the Permittee must conduct performance tests at the appropriate frequency given in Section 63.10006(c) through (e) for that pollutant until all performance tests over a consecutive 3‐year period show compliance with the LEE criteria. [40 CFR 63.10006(h), Minn. R. 7011.0563]

5.6.60 If the Permittee is required to meet an applicable tune‐up work practice standard, the Permittee must conduct a performance tune‐up according to Section 63.10021(e). (1) For EGUs not employing neural network combustion optimization during normal operation, each performance tune‐up specified in Section 63.10021(e) must be no more than 36 calendar months after the previous performance tune‐up. (2) For EGUs employing neural network combustion optimization systems during normal operation, each performance tune‐up specified in Section 63.10021(e) must be no more than 48 calendar months after the previous performance tune‐up. [40 CFR 63.10006(i), Minn. R. 7011.0563]

5.6.61 The Permittee must report the results of performance tests and performance tune‐ups within 60 days after the completion of the performance tests and performance tune‐ups. The reports for all subsequent performance tests must include all applicable information required in Section 63.10031. [40 CFR 63.10006(j), Minn. R. 7011.0563]

5.6.62 Except as otherwise provided in Section 63.10007, the Permittee must conduct all required performance tests according to Section 63.7(d), (e), (f), and (h). The Permittee must also develop a site‐specific test plan according to the requirements in Section 63.7(c). (1) If the Permittee uses CEMS (Hg, HCl, SO2, or other) to determine compliance with a 30‐ (or, if applicable, 90‐) boiler operating day rolling average emission limit, the Permittee must collect quality‐ assured CEMS data for all EQUI64 operating conditions, including startup and shutdown (see Section 63.10011(g) and Table 3 to subp. UUUUU), except as


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation otherwise provided in Section 63.10020(b). Emission rates determined during startup periods and shutdown periods (as defined in Section 63.10042) are not to be included in the compliance determinations, except as otherwise provided in Sections 63.10000(c)(1)(vi)(B) and 63.10005(a)(2)(iii). (2) If the Permittee conducts performance testing with test methods in lieu of continuous monitoring, operate EQUI64 at maximum normal operating load conditions during each periodic (e.g., quarterly) performance test. Maximum normal operating load will be generally between 90 and 110 percent of design capacity but should be representative of site specific normal operations during each test run. (3) For establishing operating limits with particulate matter continuous parametric monitoring system (PM CPMS) to demonstrate compliance with a PM or non Hg metals emissions limit, operate EQUI64 at maximum normal operating load conditions during the performance test period. Maximum normal operating load will be generally between 90 and 110 percent of design capacity but should be representative of site specific normal operations during each test run. [40 CFR 63.10007(a), Minn. R. 7011.0563]

5.6.63 The Permittee must conduct each performance test (including traditional 3‐run stack tests, 30‐boiler operating day tests based on CEMS (or sorbent trap monitoring system) data, and 30‐boiler operating day Hg emission tests for LEE qualification) according to requirements in subp. UUUUU Table 5. For PM, a. Install, certify, operate, and maintain a PM CEMS according to pt. 60, Appendix B Performance Specification (PS) 11 and App. F PS 2; b. Install, certify, operate, and maintain the diluent gas, flow rate, and/or moisture monitoring systems according to pt. 75 and Sections 63.10010(a), (b), (c), and (d); c. Convert hourly emissions concentrations to 30 boiler operating day rolling average lb/MMBtu or lb/MWh emissions rates according to Method 19 F‐factor methodology at pt. 60 App. A‐7, or calculate using mass emissions rate and electrical output data (see Section 63.10007(e)). For HCl and HF, a. Select sampling ports location and number of traverse points according to pt. 60 App. A‐1 Method 1; b. Determine stack gas velocity and volumetric flow‐rate using pt. 60 App. A‐1 or A‐2 Method 2, 2A, 2C, 2F, 2G or 2H; c. Determine stack gas O2 and CO2 concentrations using pt. 60 App. A‐2 Method 3A or 3B, or ANSI/ASME PTC 19.10‐1981;


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation d. Measure stack gas moisture content using pt. 60 App. A‐3 Method 4; e. Measure HCl and HF emissions concentrations using pt. 60 App. A‐8 Method 26 or 26A or pt. 63 App. A Method 320 or ASTM 6348‐03 with (1) additional quality assurance measures in Table 5 footnote 4 and (2) spiking levels nominally no greater than two times the level corresponding to the applicable emission limit. Method 26A must be used if there are entrained water droplets in the exhaust stream; f. Convert emissions concentration to lb/MMBtu or lb/MWh emissions rates using pt. 60 App. A‐7 Method 19 F‐factor methodology, or calculate using mass emissions rate and electrical output data (see Section 63.10007(e)). For Hg LEE testing, a. Select sampling ports location and number of traverse points using single point located at the 10% centroidal area of the duct at a port location per pt. 60 App. A‐1 Method 1 or App. 8 Method 30B for Method 30B point selection; b. Determine stack gas velocity and volumetric flow‐rate using pt. 60 App. A‐1 Method 2, 2A, 2C, 2F, 2G, or 2H or flow monitoring system certified per App. A of subp. UUUUU; c. Determine stack gas O2 and CO2 concentrations using pt. 60 App. A‐1 Method 3A or 3B, or ANSI/ASME PTC 19.10‐1981, or diluent gas monitoring systems certified according to pt. 75; d. Measure stack gas moisture content using pt. 60 App. A‐3 Method 4, or moisture monitoring systems certified according to pt. 75; e. Measure Hg emission concentration using pt. 60 App. A‐8 Method 30B; perform a 30 operating day test, with a maximum of 10 operating days per run (i.e., per pair of sorbent traps) or sorbent trap monitoring system or Hg CEMS certified per subp. UUUUU App. A; f. Convert emissions concentrations from the LEE test to lb/TBtu or lb/GWh emissions rates using pt. 60 App. A‐7 Method 19 F‐factor methodology, or calculate using mass emissions rate and electrical output data (see Section 63.10007(e)); g. Convert average lb/TBtu or lb/GWh Hg emission rate to lb/year, if attempting to meet the 22.0 lb/year threshold using potential maximum annual heat input in TBtu or potential maximum electricity generated in GWh. For SO2, a. Install, certify, operate, and maintain CEMS according to pt. 75 and Sections 63.10010(a) and (f); b. Install, operate, and maintain the diluent gas, flow rate, and/or moisture monitoring systems according to pt. 75 and Sections 63.10010(a), (b), (c), and (d);


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation c. Convert hourly emissions concentrations to 30 boiler operating day rolling average lb/MMBtu or lb/MWh emissions rates using pt. 60 App. A‐7 Method 19 F‐factor methodology, or calculate using mass emissions rate and electrical output data (see Section 63.10007(e)). [40

5.6.64 Except for a 30‐boiler operating day performance test based on CEMS (or sorbent trap monitoring system) data, where the concept of test runs does not apply, the Permittee must conduct a minimum of three separate test runs for each performance test, as specified in Section 63.7(e)(3). Each test run must comply with the minimum applicable sampling time or volume specified in Table 2 to subp. UUUUU. Sections 63.10005(d) and (h), respectively, provide special instructions for conducting performance tests based on CEMS or sorbent trap monitoring systems, and for conducting emission tests for LEE qualification. [40 CFR 63.10007(d), Minn. R. 7011.0563]

5.6.65 To use the results of performance testing to determine compliance with the applicable emission limits in Table 2 to subp. UUUUU, proceed as follows: (1) Except for a 30‐boiler operating day performance test based on CEMS (or sorbent trap monitoring system) data, if measurement results for any pollutant are reported as below the method detection level (e.g., laboratory analytical results for one or more sample components are below the method defined analytical detection level), the Permittee must use the method detection level as the measured emissions level for that pollutant in calculating compliance. The measured result for a multiple component analysis (e.g., analytical values for multiple Method 29 fractions both for individual HAP metals and for total HAP metals) may include a combination of method detection level data and analytical data reported above the method detection level. [40 CFR 63.10007(e)(1), Minn. R. 7011.0563]

5.6.66 (2) If the limits are expressed in lb/MMBtu or lb/TBtu, the Permittee must use the F‐factor methodology and equations in sections 12.2 and 12.3 of EPA Method 19 in appendix A‐7 to part 60 of this chapter. In cases where an appropriate F‐factor is not listed in Table 19‐2 of Method 19, the Permittee may use F‐factors from Table 1 in section 3.3.5 of appendix F to part 75 of this chapter, or F‐factors derived using the procedures in section 3.3.6 of appendix to part 75 of this chapter. Use the following factors to convert the pollutant concentrations measured during the initial performance tests to units of lb/scf, for use in the applicable Method 19 equations: (i) Multiply SO2 ppm by 1.66 x 1E‐7; (ii) Multiply HCl ppm by 9.43 x 1E‐8;


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation (iii) Multiply HF ppm by 5.18 x 1E‐8; (iv) Multiply HAP metals concentrations (mg/dscm) by 6.24 x 1E‐8; and (v) Multiply Hg concentrations (ug/scm) by 6.24 x 1E‐11. [40 CFR 63.10007(e)(2), Minn. R. 7011.0563]

5.6.67 To determine compliance with emission limits expressed in lb/MWh or lb/GWh, the Permittee must first calculate the pollutant mass emission rate during the performance test, in units of lb/h. For Hg, if a CEMS or sorbent trap monitoring system is used, use Equation A‐2 or A‐3 in appendix A to subp. UUUUU (as applicable). In all other cases, use an equation that has the general form of Equation A‐2 or A‐3, replacing the value of K with 1.66E‐7 lb/scf‐ppm for SO2, 9.43E‐8 lb/scf‐ppm for HCl (if an HCl CEMS is used), 5.18E‐8 lb/scf‐ppm for HF (if an HF CEMS is used), or 6.24E‐8 lb‐scm/mg‐scf for HAP metals and for HCl and HF (when performance stack testing is used), and defining Ch as the average SO2, HCl, or HF concentration in ppm, or the average HAP metals concentration in mg/dscm. This calculation requires stack gas volumetric flow rate (scfh) and (in some cases) moisture content data (see Sections 63.10005(h)(3) and 63.10010). Then, if the applicable emission limit is in units of lb/GWh, use Equation A‐4 in appendix A to subp. UUUUU to calculate the pollutant emission rate in lb/GWh. In this calculation, define (M)h as the calculated pollutant mass emission rate for the performance test (lb/h), and define (MW)h as the average electrical load during the performance test (megawatts). If the applicable emission limit is in lb/MWh rather than lb/GWh, omit the 1E+3 term from Equation A‐4 to determine the pollutant emission rate in lb/MWh. [40 CFR 63.10007(e)(3), Minn. R. 7011.0563]

5.6.68 If the Permittee elects to (or is required to) use CEMS to continuously monitor Hg, HCl, HF, SO2, or PM emissions (or, if applicable, sorbent trap monitoring systems to continuously collect Hg emissions data), the following default values are available for use in the emission rate calculations during startup periods or shutdown periods (as defined in Section 63.10042). For the purposes of subp. UUUUU, these default values are not considered to be substitute data. [40 CFR 63.10007(f), Minn. R. 7011.0563]

5.6.69 Diluent cap values. If the Permittee uses CEMS (or, if applicable, sorbent trap monitoring systems) to comply with a heat input‐based emission rate limit, the Permittee may use the following diluent cap values for a startup or shutdown hour in which the measured CO2 concentration is below the cap value or the measured O2 concentration is above the cap value:


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation (ii) For all EGUs other than IGCC, the Permittee may use 5% for CO2 or 14% for O2. [40 CFR 63.10007(f)(1), Minn. R. 7011.0563]

5.6.70 Default electrical load. If the Permittee uses CEMS to continuously monitor Hg, HCl, HF, SO2, or PM emissions (or, if applicable, sorbent trap monitoring systems to continuously collect Hg emissions data), the following default value is available for use in the emission rate calculations during startup periods or shutdown periods (as defined in Section 63.10042). For the purposes of subp. UUUUU, this default value is not considered to be substitute data. For a startup or shutdown hour in which there is heat input to an affected EGU but zero electrical load, the Permittee must calculate the pollutant emission rate using a value equivalent to 5% of the maximum sustainable electrical output, expressed in megawatts, as defined in section 6.5.2.1(a)(1) of Appendix A to part 75 of this chapter. This default electrical load is either the nameplate capacity of the EGU or the highest electrical load observed in at least four representative quarters of EGU operation. For a monitored common stack, the default electrical load is used only when all EGUs are operating (i.e., combusting fuel) are in startup or shutdown mode, and have zero electrical generation. Under those conditions, a default electrical load equal to 5% of the combined maximum sustainable electrical load of the EGUs that are operating but have a total of zero electrical load must be used to calculate the hourly electrical output‐based pollutant emissions rate. [40 CFR 63.10007(f)(2), Minn. R. 7011.0563]

5.6.71 Upon request, the Permittee shall make available to the EPA Administrator such records as may be necessary to determine whether the performance tests have been done according to the requirements of Section 63.10007. [40 CFR 63.10007(g), Minn. R. 7011.0563]

5.6.72 General eligibility. 1) The Permittee may use emissions averaging as described in Section 63.10009(a)(2) as an alternative to meeting the requirements of Section 63.9991 for filterable PM, SO2, HF, HCl, non‐Hg HAP metals, or Hg on an EGU‐specific basis if: (i) The Permittee has more than one existing EGU in the same subcategory located at one or more contiguous properties, belonging to a single major industrial grouping, which are under common control of the same person (or persons under common control); and (ii) The Permittee uses CEMS (or sorbent trap monitoring systems for determining Hg emissions) or quarterly emissions


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation testing for demonstrating compliance. [40 CFR 63.10009(a), Minn. R. 7011.0563]

5.6.73 (2) The Permittee may demonstrate compliance by emissions averaging among the existing EGUs in the same subcategory, if the Permittee's averaged Hg emissions for EGUs in the "unit designed for coal >=8,300 Btu/lb" subcategory are equal to or less than 1.0 lb/TBtu or 1.1E‐2 lb/GWh or if your averaged emissions of individual, other pollutants from other subcategories of such EGUs are equal to or less than the applicable emissions limit in Table 2 of subp. UUUUU, according to the procedures in Section 63.10009. Note that except for Hg emissions from EGUs in the "unit designed for coal >=8,300 Btu/lb" subcategory, the averaging time for emissions averaging for pollutants is 30 days (rolling daily) using data from CEMS or a combination of data from CEMS and manual performance testing. The averaging time for emissions averaging for Hg from EGUs in the "unit designed for coal >=8,300 Btu/lb" subcategory is 90 days (rolling daily) using data from CEMS, sorbent trap monitoring, or a combination of monitoring data and data from manual performance testing. For the purposes of Section 63.10009(a)(2), 30‐ (or 90‐day) group boiler operating days is defined as a period during which at least one unit in the emissions averaging group has operated 30 (or 90) days. The Permittee must calculate the weighted average emissions rate for the group in accordance with the procedures in Section 63.10009(a)(2) using the data from all units in the group including any that operate fewer than 30 (or 90) days during the preceding 30 (or 90) group boiler days. [40 CFR 63.10009(a), Minn. R. 7011.0563]

5.6.74 (i) The Permittee may choose to have its EGU emissions averaging group meet either the heat input basis (MMBtu or TBtu, as appropriate for the pollutant) or gross electrical output basis (MWh or GWh, as appropriate for the pollutant). (ii) the Permittee may not mix bases within your EGU emissions averaging group. (iii) The Permittee may use emissions averaging for affected units in different subcategories if the units vent to the atmosphere through a common stack (see Section 63.10009(m)). [40 CFR 63.10009(a)(2), Minn. R. 7011.0563]

5.6.75 Equations. Use the equations at Section 63.10009(b) and located in Appendix E of this permit when performing calculations for your EGU emissions averaging group. (1) Group eligibility equations. Use Equations 1a and 1b in Appendix E (2) Weighted 30‐boiler operating day rolling average


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation emissions rate equations for pollutants other than Hg. Use equation 2a or 2b in Appendix E to calculate the 30 day rolling average emissions daily. (3) Weighted 90‐boiler operating day rolling average emissions rate equations for Hg emissions from EGUs in the "coal‐fired unit not low rank virgin coal" subcategory. Use equation 3a or 3b in Appendix E to calculate the 90‐day rolling average emissions daily. [40 CFR 63.10009(b), Minn. R. 7011.0563]

5.6.76 Separate stack requirements. For a group of two or more existing EGUs in the same subcategory that each vent to a separate stack, the Permittee may average filterable PM, SO2, HF, HCl, non‐Hg HAP metals, or Hg emissions to demonstrate compliance with the limits in Table 2 to subp. UUUUUU if the Permittee satisfies the requirements in Section 63.10009(d) through (j). [40 CFR 63.10009(c), Minn. R. 7011.0563]

5.6.77 For each existing EGU in the averaging group: (1) The emissions rate achieved during the initial performance test for the HAP being averaged must not exceed the emissions level that was being achieved 180 days after April 16, 2015, or the date on which emissions testing done to support the Permittee's emissions averaging plan is complete (if the Administrator does not require submission and approval of the Permittee's emissions averaging plan), or the date the Permittee begins emissions averaging, whichever is earlier; or (2) The control technology employed during the initial performance test must not be less than the design efficiency of the emissions control technology employed 180 days after April 16, 2015 or the date the Permittee begins emissions averaging, whichever is earlier. [40 CFR 63.10009(d), Minn. R. 7011.0563]

5.6.78 The weighted‐average emissions rate from the existing EGUs participating in the emissions averaging option must be in compliance with the limits in Table 2 to subp. UUUUU at all times following the compliance date specified 180 days after April 16, 2015, or the date on which the Permittee completes the emissions measurements used to support its emissions averaging plan (if the Administrator does not require submission and approval of the Permittee's emissions averaging plan), or the date that the Permittee begins emissions averaging, whichever is earlier. [40 CFR 63.10009(e), Minn. R. 7011.0563]

5.6.79 Emissions averaging group eligibility demonstration. The Permittee must demonstrate the ability for the EGUs included in the emissions averaging group to demonstrate initial compliance according to Section 63.10009(f)(1) or (2) using the


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation maximum normal operating load of each EGU and the results of the initial performance tests. For this demonstration and prior to the Permittee submitting its emissions averaging plan, if requested, the Permittee must conduct required emissions monitoring for 30 days of boiler operation and any required manual performance testing to calculate an initial weighted average emissions rate in accordance with this section. Should the Administrator require approval, the Permittee must submit its proposed emissions averaging plan and supporting data at least 120 days before April 16, 2015. If the Administrator requires approval of the Permittee's plan, the Permittee may not begin using emissions averaging until the Administrator approves the plan. [40 CFR 63.10009(f), Minn. R. 7011.0563]

5.6.80 (1) The Permittee must use Equation 1a in Section 63.10009(b) to demonstrate that the maximum weighted average emissions rates of filterable PM, HF, SO2, HCl, non‐Hg HAP metals, or Hg emissions from the existing units participating in the emissions averaging option do not exceed the emissions limits in Table 2 to subp. UUUUU. (2) If the Permittee is not capable of monitoring heat input or gross electrical output, and the EGU generates steam for purposes other than generating electricity, the Permittee may use Equation 1b in Section 63.10009(b) as an alternative to using Equation 1a of Section 63.10009(b) to demonstrate that the maximum weighted average emissions rates of filterable PM, HF, SO2, HCl, non‐Hg HAP metals, or Hg emissions from the existing units participating in the emissions averaging group do not exceed the emission limits in Table 2 to subp. UUUUU. [40 CFR 63.10009(f)(1) & (2), Minn. R. 7011.0563]

5.6.81 The Permittee must determine the weighted average emissions rate in units of the applicable emissions limit on a 30 day rolling average (90 day rolling average for Hg) basis according to Section 63.10009(g)(1) through (2). The first averaging period begins on 30 (or 90 for Hg) days after February 16, 2015 or the date the Permittee begins emissions averaging, whichever is earlier. (1) The Permittee must use Equation 2a or 3a of Section 63.10009(b) to calculate the weighted average emissions rate using the actual heat input or gross electrical output for each existing unit participating in the emissions averaging option. (2) If the Permittee is not capable of monitoring heat input or gross electrical output, the Permittee may use Equation 2b or 3b of Section 63.10009(b) as an alternative to using Equation 2a of Section 63.10009(b) to calculate the average weighted emission rate using the actual steam generation from the units participating in the emissions averaging option. [40 CFR


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 63.10009(g), Minn. R. 7011.0563]

5.6.82 CEMS (or sorbent trap monitoring) use. If an EGU in the Permittee's emissions averaging group uses CEMS (or a sorbent trap monitor for Hg emissions) to demonstrate compliance, the Permittee must use those data to determine the 30 (or 90) group boiler operating day rolling average emissions rate. [40 CFR 63.10009(h), Minn. R. 7011.0563]

5.6.83 Emissions testing. If the Permittee uses manual emissions testing to demonstrate compliance for one or more EGUs in the Permittee's emissions averaging group, the Permittee must use the results from the most recent performance test to determine the 30 (or 90) day rolling average. The Permittee may use CEMS or sorbent trap data in combination with data from the most recent manual performance test in calculating the 30 (or 90) group boiler operating day rolling average emissions rate. [40 CFR 63.10009(i), Minn. R. 7011.0563]

5.6.84 Emissions averaging plan. The Permittee must develop an implementation plan for emissions averaging according to the following procedures and requirements in Section 63.10009(j)(1) and (2). (1) The Permittee must include the information contained in Section 63.10009(j)(1)(i) through (v) in its implementation plan for all the emissions units included in an emissions averaging: (i) The identification of all existing EGUs in the emissions averaging group, including for each either the applicable HAP emission level or the control technology installed as of 180 days after February 16, 2015, or the date on which the Permittee completes the emissions measurements used to support its emissions averaging plan (if the Administrator does not require submission and approval of the Permittee's emissions averaging plan), or the date the Permittee begins emissions averaging, whichever is earlier; and the date on which the Permittee is requesting emissions averaging to commence; (ii) The process weighting parameter (heat input, gross electrical output, or steam generated) that will be monitored for each averaging group; (iii) The specific control technology or pollution prevention measure to be used for each emission EGU in the averaging group and the date of its installation or application. If the pollution prevention measure reduces or eliminates emissions from multiple EGUs, the Permittee must identify each EGU; (iv) The means of measurement (e.g., CEMS, sorbent trap monitoring, manual performance test) of filterable PM, SO2,


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation HF, HCl, individual or total non‐Hg HAP metals, or Hg emissions in accordance with the requirements in Section 63.10007 and to be used in the emissions averaging calculations; and (v) A demonstration that emissions averaging can produce compliance with each of the applicable emission limit(s) in accordance with Section 63.10009(b)(1). [40 CFR 63.10009(j), Minn. R. 7011.0563]

5.6.85 If the Administrator requests the Permittee to submit the plan for review and approval, the Permittee must submit a complete implementation plan at least 120 days before April 16, 2015. If the Administrator requests the Permittee to submit the plan for review and approval, the Permittee must receive approval before initiating emissions averaging. (i) The Administrator shall use following criteria in reviewing and approving or disapproving the plan: (A) Whether the content of the plan includes all of the information specified in section 63.10009(j)(1); and (B) Whether the plan presents information sufficient to determine that compliance will be achieved and maintained. (ii) The Administrator shall not approve an emissions averaging implementation plan containing any of the following provisions: (A) Any averaging between emissions of different pollutants or between units located at different facilities; or (B) The inclusion of any emissions unit other than an existing unit in the same subcategory. [40 CFR 63.10009(j)(2), Minn. R. 7011.0563]

5.6.86 Flue gases from the affected units under subp. UUUUU exhaust to the atmosphere through a variety of different configurations, including but not limited to individual stacks, a common stack configuration or a main stack plus a bypass stack. For the CEMS, PM CPMS, and sorbent trap monitoring systems used to provide data under subp. UUUUU, the continuous monitoring system installation requirements for these exhaust configurations are as follows: (1) Single unit‐single stack configurations. For EQUI64 (an affected unit) that exhausts to the atmosphere through a single, dedicated stack (STRU1), the Permittee shall either install the required CEMS, PM CPMS, and sorbent trap monitoring systems in the stack or at a location in the ductwork downstream of all emissions control devices, where


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation the pollutant and diluents concentrations are representative of the emissions that exit to the atmosphere. [40 CFR 63.10010(a)(1), Minn. R. 7011.0563]

5.6.87 If the Permittee uses an oxygen (O2) or carbon dioxide (CO2) CEMS to convert measured pollutant concentrations to the units of the applicable emissions limit, the O2 or CO2 concentrations shall be monitored at a location that represents emissions to the atmosphere, i.e., at the outlet of the EGU, downstream of all emission control devices. The Permittee must install, certify, maintain, and operate the CEMS according to part 75 of this chapter. Use only quality‐assured O2 or CO2 data in the emissions calculations; do not use part 75 substitute data values. [40 CFR 63.10010(b), Minn. R. 7011.0563]

5.6.88 If the Permittee is required to use a stack gas flow rate monitor, either for routine operation of a sorbent trap monitoring system or to convert pollutant concentrations to units of an electrical output‐based emission standard in Table 2 to subp. UUUUU, the Permittee must install, certify, operate, and maintain the monitoring system and conduct on‐going quality‐assurance testing of the system according to part 75 of this chapter. Use only unadjusted, quality‐assured flow rate data in the emissions calculations. Do not apply bias adjustment factors to the flow rate data and do not use substitute flow rate data in the calculations. [40 CFR 63.10010(c), Minn. R. 7011.0563]

5.6.89 If the Permittee is required to make corrections for stack gas moisture content when converting pollutant concentrations to the units of an emission standard in Table 1 of 2 to subp. UUUUU, the Permittee must install, certify, operate, and maintain a moisture monitoring system in accordance with part 75 of this chapter. Alternatively, for coal‐fired units, you may use appropriate fuel‐specific default moisture values from Section 75.11(b) of this chapter to estimate the moisture content of the stack gas or the Permittee may petition the Administrator under Section 75.66 of this chapter for use of a default moisture value for non‐coal‐fired units. If the Permittee installs and operates a moisture monitoring system, do not use substitute moisture data in the emissions calculations. [40 CFR 63.10010(d), Minn. R. 7011.0563]

5.6.90 If the Permittee uses an HCl and/or HF CEMS, the Permittee must install, certify, operate, maintain, and quality‐assure the data from the monitoring system in accordance with appendix B to subp. UUUUU. Calculate and record a 30‐boiler operating day rolling average HCl or HF emission rate in the units of the standard, updated after each new boiler operating day. Each 30‐boiler operating day rolling average emission rate is the average of all the valid hourly HCl or HF emission rates in the preceding 30 boiler operating days (see section 9.4 of


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation appendix B to subp. UUUUU). [40 CFR 63.10010(e), Minn. R. 7011.0563]

5.6.91 (1) If the Permittee uses an SO2 CEMS, the Permittee must install the monitor at the outlet of the EGU, downstream of all emission control devices, and must certify, operate, and maintain the CEMS according to part 75 of this chapter. (2) For on‐going QA, the SO2 CEMS must meet the applicable daily, quarterly, and semiannual or annual requirements in sections 2.1 through 2.3 of appendix B to part 75 of this chapter, with the following addition: The Permittee must perform the linearity checks required in section 2.2 of appendix B to part 75 of this chapter if the SO2 CEMS has a span value of 30 ppm or less. [40 CFR 63.10010(f)(1) & (2), Minn. R. 7011.0563]

5.6.92 (3) Calculate and record a 30‐boiler operating day rolling average SO2 emission rate in the units of the standard, updated after each new boiler operating day. Each 30‐boiler operating day rolling average emission rate is the average of all of the valid SO2 emission rates in the preceding 30 boiler operating days. (4) Use only unadjusted, quality‐assured SO2 concentration values in the emissions calculations; do not apply bias adjustment factors to the part 75 SO2 data and do not use part 75 substitute data values. For startup or shutdown hours (as defined in Section 63.10042) the default electrical load and the diluent cap are available for use in the hourly SO2 emission rate calculations, as described in Section 63.10007(f). Use a flag to identify each startup or shutdown hour and report a special code if the diluent cap or default electrical load is used to calculate the SO2 emission rate for any of these hours. [40 CFR 63.10010(f)(3) & (4), Minn. R. 7011.0563]

5.6.93 If the Permittee uses a Hg CEMS or a sorbent trap monitoring system, the Permittee must install, certify, operate, maintain and quality‐assure the data from the monitoring system in accordance with appendix A to subp. UUUUU. The Permittee must calculate and record a 30‐ (or, if alternate emissions averaging is used, 90‐) boiler operating day rolling average Hg emission rate, in units of the standard, updated after each new boiler operating day. Each 30‐ (or, if alternate emissions averaging is used, 90‐) boiler operating day rolling average emission rate, calculated according to section 6.2 of appendix A to subp. UUUUU, is the average of all of the valid hourly Hg emission rates in the preceding 30‐ (or, if alternate emissions averaging is used, a 90‐) boiler operating days. Section 7.1.4.3 of appendix A to subp. UUUUU explains how to reduce sorbent trap monitoring system data to an hourly basis. [40 CFR 63.10010(g), Minn. R. 7011.0563]


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 5.6.94 If the Permittee chooses to comply with the PM filterable

emissions limit in lieu of metal HAP limits, the Permittee may choose to install, certify, operate, and maintain a PM CEMS and record the output of the PM CEMS as specified in Section 63.10010(i)(1) through (5). The compliance limit will be expressed as a 30‐boiler operating day rolling average of the numerical emissions limit value applicable for the Permittee's unit in Table 2 to subp. UUUUU. (1) The Permittee shall install and certify the PM CEMS according to the procedures and requirements in Performance Specification 11‐Specifications and Test Procedures for Particulate Matter Continuous Emission Monitoring Systems at Stationary Sources in Appendix B to part 60, using Method 5 at Appendix A‐3 to part 60 and ensuring that the front half filter temperature shall be 160 degrees +/‐14 degrees C (320 degrees +/‐25 degrees F). The reportable measurement output from the PM CEMS must be expressed in units of the applicable emissions limit (e.g., lb/MMBtu, lb/MWh). [40 CFR 63.10010(i), Minn. R. 7011.0563]

5.6.95 (2) The Permittee shall operate and maintain the PM CEMS according to the procedures and requirements in Procedure 2‐Quality Assurance Requirements for Particulate Matter Continuous Emission Monitoring Systems at Stationary Sources in Appendix F to part 60 of this chapter. (i) The Permittee must conduct the relative response audit (RRA) for the PM CEMS at least once annually. (ii) The Permittee must conduct the relative correlation audit (RCA) for the PM CEMS at least once every 3 years. [40 CFR 63.10010(i), Minn. R. 7011.0563]

5.6.96 (3) Collect PM CEMS hourly average output data for all boiler operating hours except as indicated in Section 63.10010(i). (4) Calculate the arithmetic 30‐boiler operating day rolling average of all of the hourly average PM CEMS output data collected during all nonexempt boiler operating hours. [40 CFR 63.10010(i), Minn. R. 7011.0563]

5.6.97 The Permittee must collect data using the PM CEMS at all times the process unit is operating and at the intervals specified in Section 63.10010(a), except for periods of monitoring system malfunctions, repairs associated with monitoring system malfunctions, and required monitoring system quality assurance or quality control activities. (i) The Permittee must use all the data collected during all boiler operating hours in assessing the compliance with the applicable operating limit except:


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation (A) Any data collected during monitoring system malfunctions, repairs associated with monitoring system malfunctions, or required monitoring system quality assurance or control activities conducted during monitoring system malfunctions in calculations and report any such periods in the Permittee's annual deviation report; (B) Any data collected during periods when the monitoring system is out of control as specified in the Permittee's site‐specific monitoring plan, repairs associated with periods when the monitoring system is out of control, or required monitoring system quality assurance or control activities conducted during out of control periods in calculations used to report emissions or operating levels and report any such periods in the Permittee's annual deviation report; (C) Any data recorded during periods of startup or shutdown. [40 CFR 63.10010(i)(5)(i), Minn. R. 7011.0563]

5.6.98 The Permittee must record and make available upon request results of PM CEMS system performance audits, dates and duration of periods when the PM CEMS is out of control to completion of the corrective actions necessary to return the PM CEMS to operation consistent with the Permittee's site‐specific monitoring plan. [40 CFR 63.10010(i)(5)(ii), Minn. R. 7011.0563]

5.6.99 The Permittee must install, certify, operate, maintain, and quality assure each monitoring system necessary for demonstrating compliance with the PM or non‐mercury metals work practice standards for startup periods. (1) The Permittee shall develop a site‐specific monitoring plan for PM or non‐mercury metals work practice monitoring during startup periods. (2) The Permittee shall submit the site‐specific monitoring plan upon request by the Administrator. (3) The provisions of the monitoring plan must address the following items: (i) Monitoring system installation; (ii) Performance and equipment specifications; (iii) Schedule for initial and periodic performance evaluations; (iv) Performance evaluation procedures and acceptance criteria;


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation (v) On‐going operation and maintenance procedures; and (vi) On‐going recordkeeping and reporting procedures. (4) The Permittee may rely on monitoring system specifications or instructions to address Section 63.10010(l)(3)(i) through (vi). (5) The Permittee must operate and maintain the monitoring system according to the site‐specific monitoring plan. [40 CFR 63.10010(l), Minn. R. 7011.0563]

5.6.100 The Permittee must demonstrate initial compliance with each applicable emissions limit by conducting performance testing. [40 CFR 63.10011(a), Minn. R. 7011.0563]

5.6.101 For a unit that uses a CEMS to measure SO2 or PM emissions for initial compliance, the first 30 boiler operating day average emission rate obtained with certified CEMS after the applicable date in Section 63.9984 (or, if applicable, prior to that date, as described in Section 63.10005(b)(2)), expressed in units of the standard, is the initial performance test. Initial compliance is demonstrated if the results of the performance test meet the applicable SO2 or filterable PM emission limit in Table 2 to subp. UUUUU. [40 CFR 63.10011(c)(2), Minn. R. 7011.0563]

5.6.102 For candidate LEE units, use the results of the performance testing described in Section 63.10005(h) to determine initial compliance with the applicable emission limit(s) in Table 2 to subp. UUUUU and to determine whether the unit qualifies for LEE status. [40 CFR 63.10011(d), Minn. R. 7011.0563]

5.6.103 The Permittee must submit a Notification of Compliance Status containing the results of the initial compliance demonstration, according to Section 63.10030(e). [40 CFR 63.10011(e), Minn. R. 7011.0563]

5.6.104 (1) The Permittee must determine the fuel whose combustion produces the least uncontrolled emissions, i.e., the cleanest fuel, either natural gas or distillate oil, that is available on site or accessible nearby for use during periods of startup or shutdown. (2) The Permittee's cleanest fuel, either natural gas or distillate oil, for use during periods of startup or shutdown determination may take safety considerations into account. [40 CFR 63.10011(f)(1) & (2), Minn. R. 7011.0563]

5.6.105 The Permittee must follow the startup or shutdown requirements as given in Table 3 to subp. UUUUU for each coal‐fired, liquid oil‐fired, or solid oil‐derived fuel‐fired EGU. (1) The Permittee may use the diluent cap and default


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation electrical load values, as described in Section 63.10007(f), during startup periods or shutdown periods. (2) The Permittee must operate all CMS, collect data, calculate pollutant emission rates, and record data during startup periods or shutdown periods. (3) The Permittee must report the information as required in Section 63.10031. [40 CFR 63.10011(g), Minn. R. 7011.0563]

5.6.106 If the Permittee chooses to use paragraph (2) of the definition of "startup" in Section 63.10042 and the Permittee finds that it is unable to safely engage and operate its particulate matter (PM) control(s) within 1 hour of first firing of coal, the Permittee may choose to rely on paragraph (1) of definition of "startup" in Section 63.10042 or the Permittee may submit a request to use an alternative non‐opacity emissions standard, as described below. (i) As mentioned in Section 63.6(g)(1), the request will be published in the Federal Register for notice and comment rulemaking. Until promulgation in the Federal Register of the final alternative non‐opacity emission standard, the Permittee shall comply with paragraph (1) of the definition of "startup" in section 63.10042. the Permittee shall not implement the alternative non‐opacity emissions standard until promulgation in the Federal Register of the final alternative non‐opacity emission standard. (ii) The request need not address the items contained in Section 63.6(g)(2). (iii) The request shall provide evidence of a documented manufacturer‐identified safely issue. (iv) The request shall provide information to document that the PM control device is adequately designed and sized to meet the PM emission limit applicable to the EGU. [40 CFR 63.10011(g)(4), Minn. R. 7011.0563]

5.6.107 (v) In addition, the request shall contain documentation that: (A) The EGU is using clean fuels to the maximum extent possible to bring the EGU and PM control device up to the temperature necessary to alleviate or prevent the identified safety issues prior to the combustion of primary fuel in the EGU; (B) The EGU has explicitly followed the manufacturer's procedures to alleviate or prevent the identified safety issue; and


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation (C) Identifies with specificity the details of the manufacturer's statement of concern. (vi) The request shall specify the other work practice standards the Permittee will take to limit HAP emissions during startup periods and shutdown periods to ensure a control level consistent with the work practice standards of the final rule. (vii) The Permittee must comply with all other work practice requirements, including but not limited to data collection, recordkeeping, and reporting requirements. [40 CFR 63.10011(g)(4), Minn. R. 7011.0563]

5.6.108 The Permittee must monitor and collect data according to Section 63.10020 and the site‐specific monitoring plan required by Section 63.10000(d). [40 CFR 63.10020(a), Minn. R. 7011.0563]

5.6.109 The Permittee must operate the monitoring system and collect data at all required intervals at all times that the affected EGU is operating, except for periods of monitoring system malfunctions or out‐of‐control periods (see Section 63.8(c)(7)), and required monitoring system quality assurance or quality control activities, including, as applicable, calibration checks and required zero and span adjustments. The Permittee is required to affect monitoring system repairs in response to monitoring system malfunctions and to return the monitoring system to operation as expeditiously as practicable. [40 CFR 63.10020(b), Minn. R. 7011.0563]

5.6.110 The Permittee may not use data recorded during EGU startup or shutdown in calculations used to report emissions, except as otherwise provided in Sections 63.10000(c)(1)(vi)(B) and 63.10005(a)(2)(iii). In addition, data recorded during monitoring system malfunctions or monitoring system out‐of‐control periods, repairs associated with monitoring system malfunctions or monitoring system out‐of‐control periods, or required monitoring system quality assurance or control activities may not be used in calculations used to report emissions or operating levels. The Permittee must use all of the quality‐assured data collected during all other periods in assessing the operation of the control device and associated control system. [40 CFR 63.10020(c), Minn. R. 7011.0563]

5.6.111 Except for periods of monitoring system malfunctions or monitoring system out‐of‐control periods, repairs associated with monitoring system malfunctions or monitoring system out‐of‐control periods, and required monitoring system quality assurance or quality control activities including, as applicable, calibration checks and required zero and span adjustments), failure to collect required data is a deviation from the monitoring requirements. [40 CFR 63.10020(d), Minn. R.


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 7011.0563]

5.6.112 Additional requirements during startup periods or shutdown periods. (1) During each period of startup, the Permittee must record for each EGU: (i) The date and time that clean fuels being combusted for the purpose of startup begins; (ii) The quantity and heat input of clean fuel for each hour of startup; (iii) The electrical load for each hour of startup; (iv) The date and time that non‐clean fuel combustion begins; and (v) The date and time that clean fuels being combusted for the purpose of startup ends. (2) During each period of shutdown, the Permittee must record for each EGU: (i) The date and time that clean fuels being combusted for the purpose of shutdown begins; (ii) The quantity and heat input of clean fuel for each hour of shutdown; (iii) The electrical load for each hour of shutdown; (iv) The date and time that non‐clean fuel combustion ends; and (v) The date and time that clean fuels being combusted for the purpose of shutdown ends. [40 CFR 63.10020(e)(1) & (2), Minn. R. 7011.0563]

5.6.113 For PM or non‐mercury HAP metals work practice monitoring during startup periods, the Permittee must monitor and collect data according to Section 63.10020(e) and the site‐specific monitoring plan required by Section 63.10011(l). [40 CFR 63.10020(e)(3), Minn. R. 7011.0563]

5.6.114 The Permittee must demonstrate continuous compliance with each applicable emissions limit, operating limit, and work practice standard in Tables 1 through 4 to subp. UUUUU, according to the monitoring specified in Tables 6 and 7 to subp. UUUUU and Section 63.10021(b) through (g). [40 CFR 63.10021(a), Minn. R. 7011.0563]


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 5.6.115 Except as otherwise provided in Section 63.10020(c), if the

Permittee uses a CEMS to measure SO2, PM, HCl, HF, or Hg emissions, or using a sorbent trap monitoring system to measure Hg emissions, the Permittee must demonstrate continuous compliance by using all quality‐assured hourly data recorded by the CEMS (or sorbent trap monitoring system) and the other required monitoring systems (e.g., flow rate, CO2, O2, or moisture systems) to calculate the arithmetic average emissions rate in units of the standard on a continuous 30‐boiler operating day (or, if alternate emissions averaging is used for Hg, 90‐boiler operating day) rolling average basis, updated at the end of each new boiler operating day. Use Equation 8 in Appendix E of this permit to determine the 30‐ (or, if applicable, 90‐) boiler operating day rolling average. [40 CFR 63.10021(b), Minn. R. 7011.0563]

5.6.116 If the Permittee uses quarterly performance testing to demonstrate compliance with one or more applicable emissions limits in Table 2 to subp. UUUUU, the Permittee (1) May skip performance testing in those quarters during which less than 168 boiler operating hours occur, except that a performance test must be conducted at least once every calendar year, and (2) Must conduct the performance test as defined in Table 5 to subp. UUUUU and calculate the results of the testing in units of the applicable emissions standard. [40 CFR 63.10021(d)(1) & (2), Minn. R. 7011.0563]

5.6.117 If the Permittee must conduct periodic performance tune‐ups of your EGU(s), as specified in Section 63.10021(e)(1) through (9), perform the first tune‐up as part of the Permittee's initial compliance demonstration. Notwithstanding this requirement, the Permittee may delay the first burner inspection until the next scheduled unit outage provided you meet the requirements of Section 63.10005. Subsequently, the Permittee must perform an inspection of the burner at least once every 36 calendar months unless its EGU employs neural network combustion optimization during normal operations in which case the Permittee must perform an inspection of the burner and combustion controls at least once every 48 calendar months. (1) As applicable, inspect the burner and combustion controls, and clean or replace any components of the burner or combustion controls as necessary upon initiation of the work practice program and at least once every required inspection period. Repair of a burner or combustion control component requiring special order parts may be scheduled as follows:


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation (i) Burner or combustion control component parts needing replacement that affect the ability to optimize NOX and CO must be installed within 3 calendar months after the burner inspection, (ii) Burner or combustion control component parts that do not affect the ability to optimize NOX and CO may be installed on a schedule determined by the operator; [40 CFR 63.10021(e)(1), Minn. R. 7011.0563]

5.6.118 (2) As applicable, inspect the flame pattern and make any adjustments to the burner or combustion controls necessary to optimize the flame pattern. The adjustment should be consistent with the manufacturer's specifications, if available, or in accordance with best combustion engineering practice for that burner type; (3) As applicable, observe the damper operations as a function of mill and/or cyclone loadings, cyclone and pulverizer coal feeder loadings, or other pulverizer and coal mill performance parameters, making adjustments and effecting repair to dampers, controls, mills, pulverizers, cyclones, and sensors; (4) As applicable, evaluate windbox pressures and air proportions, making adjustments and effecting repair to dampers, actuators, controls, and sensors; (5) Inspect the system controlling the air‐to‐fuel ratio and ensure that it is correctly calibrated and functioning properly. Such inspection may include calibrating excess O2 probes and/or sensors, adjusting overfire air systems, changing software parameters, and calibrating associated actuators and dampers to ensure that the systems are operated as designed. Any component out of calibration, in or near failure, or in a state that is likely to negate combustion optimization efforts prior to the next tune‐up, should be corrected or repaired as necessary; [40 CFR 63.10021(e)(2) ‐ (5), Minn. R. 7011.0563]

5.6.119 (6) Optimize combustion to minimize generation of CO and NOX. This optimization should be consistent with the manufacturer's specifications, if available, or best combustion engineering practice for the applicable burner type. NOX optimization includes burners, overfire air controls, concentric firing system improvements, neural network or combustion efficiency software, control systems calibrations, adjusting combustion zone temperature profiles, and add‐on controls such as SCR and SNCR; CO optimization includes burners, overfire air controls, concentric firing system improvements, neural network or combustion efficiency software, control systems calibrations, and adjusting combustion zone temperature profiles;


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation (7) While operating at full load or the predominantly operated load, measure the concentration in the effluent stream of CO and NOX in ppm, by volume, and oxygen in volume percent, before and after the tune‐up adjustments are made (measurements may be either on a dry or wet basis, as long as it is the same basis before and after the adjustments are made). The Permittee may use portable CO, NOX and O2 monitors for this measurement. EGUs employing neural network optimization systems need only provide a single pre‐ and post‐tune‐up value rather than continual values before and after each optimization adjustment made by the system; [40 CFR 63.10021(e)(6) & (7), Minn. R. 7011.0563]

5.6.120 (8) Maintain on‐site and submit, if requested by the Administrator, an annual report containing the information in Section 63.10021(e)(1) through (e)(9): (i) The concentrations of CO and NOX in the effluent stream in ppm by volume, and oxygen in volume percent, measured before and after an adjustment of the EGU combustion systems; (ii) A description of any corrective actions taken as a part of the combustion adjustment; and (iii) The type(s) and amount(s) of fuel used over the 12 calendar months prior to an adjustment, but only if the unit was physically and legally capable of using more than one type of fuel during that period; and (9) Report the dates of the initial and subsequent tune‐ups as follows: (i) If the first required tune‐up is performed as part of the initial compliance demonstration, report the date of the tune‐up in hard copy (as specified in Section 63.10030) and electronically (as specified in Section 63.10031). Report the date of each subsequent tune‐up electronically (as specified in Section 63.10031). (ii) If the first tune‐up is not conducted as part of the initial compliance demonstration, but is postponed until the next unit outage, report the date of that tune‐up and all subsequent tune‐ups electronically, in accordance with Section 63.10031. [40 CFR 63.10021(e)(8) & (9), Minn. R. 7011.0563]

5.6.121 The Permittee must submit the reports required under Section 63.10031 and, if applicable, the reports required under appendices A and B to subp. UUUUU. The electronic reports required by appendices A and B to subp. UUUUU must be sent


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation to the Administrator electronically in a format prescribed by the Administrator, as provided in Section 63.10031. CEMS data (except for PM CEMS and any approved alternative monitoring using a HAP metals CEMS) shall be submitted using EPA's Emissions Collection and Monitoring Plan System (ECMPS) Client Tool. Other data, including PM CEMS data, HAP metals CEMS data, and CEMS performance test detail reports, shall be submitted in the file format generated through use of EPA's Electronic Reporting Tool, the Compliance and Emissions Data Reporting Interface, or alternate electronic file format, all as provided for under Section 63.10031. [40 CFR 63.10021(f), Minn. R. 7011.0563]

5.6.122 The Permittee must report each instance in which it did not meet an applicable emissions limit or operating limit in Tables 1 through 4 to subp. UUUUU or failed to conduct a required tune‐up. These instances are deviations from the requirements of subp. UUUUU. These deviations must be reported according to Section 63.10031. [40 CFR 63.10021(g), Minn. R. 7011.0563]

5.6.123 The Permittee must follow the startup or shutdown requirements as given in Table 3 to subp. UUUUU for each coal‐fired EGU. (1) The Permittee may use the diluent cap and default electrical load values, as described in Section 63.10007(f), during startup periods or shutdown periods. (2) The Permittee must operate all CMS, collect data, calculate pollutant emission rates, and record data during startup periods or shutdown periods. (3) The Permittee must report the information as required in Section 63.10031. (4) The Permittee may choose to submit an alternative non‐opacity emission standard, in accordance with the requirements contained in Section 63.10011(g)(4). Until promulgation in the Federal Register of the final alternative non‐opacity emission standard, the Permittee shall comply with paragraph (1) of the definition of "startup" in Section 63.10042. [40 CFR 63.10021(h), Minn. R. 7011.0563]

5.6.124 (i) The Permittee must provide reports as specified in Section 63.10031 concerning activities and periods of startup and shutdown. [40 CFR 63.10021(i), Minn. R. 7011.0563]

5.6.125 Following the compliance date, the Permittee must demonstrate compliance with subp. UUUUU on a continuous basis by meeting the requirements of Section 63.10022(a)(1) and (4). (1) For each 30‐ (or 90‐) day rolling average period,


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation demonstrate compliance with the average weighted emissions limit for the existing units participating in the emissions averaging option as determined in Section 63.10009(f) and (g); (4) For each existing EGU participating in the emissions averaging option, operate in accordance with the startup or shutdown work practice requirements given in Table 3 to subp. UUUUU. [40 CFR 63.10022(a)(1) & (4), Minn. R. 7011.0563]

5.6.126 Any instance where the Permittee fails to comply with the continuous monitoring requirements in Section 63.10022(a)(1) is a deviation. [40 CFR 63.10022(b), Minn. R. 7011.0563]

5.6.127 (a) The Permittee must submit all of the applicable notifications in Sections 63.7(b) and (c), 63.8(e), (f)(4) and (6), and 63.9(b) through (h) by the dates specified. (b) As specified in Section 63.9(b)(2), if the Permittee starts up the EGU that is an affected source before April 16, 2012, the Permittee must submit an Initial Notification not later than 120 days after April 16, 2012. [40 CFR 63.10030(a) & (b), Minn. R. 7011.0563]

5.6.128 When the Permittee is required to conduct a performance test, the Permittee must submit a Notification of Intent to conduct a performance test at least 30 days before the performance test is scheduled to begin. [40 CFR 63.10030(d), Minn. R. 7011.0563]

5.6.129 When the Permittee is required to conduct an initial compliance demonstration as specified in Section 63.10011(a), the Permittee must submit a Notification of Compliance Status according to Section 63.9(h)(2)(ii). The Notification of Compliance Status report must contain all the information specified in Section 63.10030(e)(1) through (8), as applicable. (1) A description of the affected source(s) including identification of which subcategory the source is in, the design capacity of the source, a description of the add‐on controls used on the source, description of the fuel(s) burned, including whether the fuel(s) were determined by you or EPA through a petition process to be a non‐waste under 40 CFR 241.3, whether the fuel(s) were processed from discarded non‐hazardous secondary materials within the meaning of 40 CFR 241.3, and justification for the selection of fuel(s) burned during the performance test. (2) Summary of the results of all performance tests and fuel analyses and calculations conducted to demonstrate initial compliance including all established operating limits. [40 CFR 63.10030(e)(1) & (2), Minn. R. 7011.0563]

5.6.130 (3) Identification of whether the Permittee plans to demonstrate compliance with each applicable emission limit


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation through performance testing; fuel moisture analyses; performance testing with operating limits (e.g., use of PM CPMS); CEMS; or a sorbent trap monitoring system. (4) Identification of whether the Permittee plans to demonstrate compliance by emissions averaging. (5) A signed certification that the Permittee has met all applicable emission limits and work practice standards. (6) If the Permittee had a deviation from any emission limit, work practice standard, or operating limit, the Permittee must also submit a brief description of the deviation, the duration of the deviation, emissions point identification, and the cause of the deviation in the Notification of Compliance Status report. [40 CFR 63.10030(e)(3) ‐ (6), Minn. R. 7011.0563]

5.6.131 (7) In addition to the information required in Section 63.9(h)(2), the Permittee's notification of compliance status must include the following: (i) A summary of the results of the annual performance tests and documentation of any operating limits that were reestablished during this test, if applicable. If the Permittee is conducting stack tests once every 3 years consistent with Section 63.10006(b), the date of the last three stack tests, a comparison of the emission level the Permittee achieved in the last three stack tests to the 50 percent emission limit threshold required in Section 63.10006(i), and a statement as to whether there have been any operational changes since the last stack test that could increase emissions. (ii) Certifications of compliance, as applicable, and must be signed by a responsible official stating: (A) "This EGU complies with the requirements in Section 63.10021(a) to demonstrate continuous compliance." and (B) "No secondary materials that are solid waste were combusted in any affected unit.". [40 CFR 63.10030(e)(7), Minn. R. 7011.0563]

5.6.132 (8) Identification of whether the Permittee plans to rely on paragraph (1) or (2) of the definition of "startup" in Section 63.10042. (i) Should the Permittee chooses to rely on paragraph (2) of the definition of "startup" in Section 63.10042 for its EGU, the Permittee shall include a report that identifies: (A) The original EGU installation date;


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation (B) The original EGU design characteristics, including, but not limited to, fuel and PM controls; (C) Each design PM control device efficiency; (D) The design PM emission rate from the EGU in terms of pounds PM per MMBtu and pounds PM per hour; (E) The design time from start of fuel combustion to necessary conditions for each PM control device startup; (F) Each design PM control device efficiency upon startup of the PM control device; (G) The design EGU uncontrolled PM emission rate in terms of pounds PM per hour; [40 CFR 63.10030(e)(8)(i)(A) ‐ (G), Minn. R. 7011.0563]

5.6.133 (H) Each change from the original design that did or could have changed PM emissions, including, but not limited to, each different fuel mix, each revision to each PM control device, and each EGU revision, along with the month and year that the change occurred; (I) Current EGU PM producing characteristics, including, but not limited to, fuel mix and PM controls; (J) Current PM emission rate from the EGU in terms of pounds PM per MMBtu and pounds per hour; (K) Current PM control device efficiency from each PM control device; (L) Current time from start of fuel combustion to conditions necessary for each PM control device startup; (M) Current PM control device efficiency upon startup of each PM control device; and (N) Current EGU uncontrolled PM emission rate in terms of pounds PM per hour. [40 CFR 63.10030(e)(8)(i)(H) ‐ (N), Minn. R. 7011.0563]

5.6.134 The report shall be prepared, signed, and sealed by a professional engineer licensed in the state where the Permittee's EGU is located. Apart from preparing, signing, and sealing this report, the professional engineer shall be independent and not otherwise employed by the Permittee's company, any parent company of the Permittee's company, or any subsidiary of the Permittee's company. [40 CFR


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 63.10030(e)(8)(ii), Minn. R. 7011.0563]

5.6.135 The Permittee must submit each applicable report in Table 8 to subp. UUUUU. If the Permittee is required to (or elects to) continuously monitor Hg and/or HCl and/or HF emissions, the Permittee must also submit the electronic reports required under appendix A and/or appendix B to subp. UUUUU, at the specified frequency. [40 CFR 63.10031(a), Minn. R. 7011.0563]

5.6.136 Unless the Administrator has approved a different schedule for submission of reports under Section 63.10(a), the Permittee must submit each report by the date in Table 8 to subp. UUUUU and according to the requirements in Section 63.10031(b)(1) through (5). (1) The first compliance report must cover the period beginning on the compliance date that is specified for the Permittee's affected source in Section 63.9984 and ending on June 30 or December 31, whichever date is the first date that occurs at least 180 days after the compliance date that is specified for the Permittee's source in section 63.9984. (2) The first compliance report must be postmarked or submitted electronically no later than July 31 or January 31, whichever date is the first date following the end of the first calendar half after the compliance date that is specified for the Permittee's source in Section 63.9984. [40 CFR 63.10031(b)(1) & (2), Minn. R. 7011.0563]

5.6.137 (3) Each subsequent compliance report must cover the semiannual reporting period from January 1 through June 30 or the semiannual reporting period from July 1 through December 31. (4) Each subsequent compliance report must be postmarked or submitted electronically no later than July 31 or January 31, whichever date is the first date following the end of the semiannual reporting period. (5) For each affected source that is subject to permitting regulations pursuant to part 70 or part 71 of this chapter, and if the permitting authority has established dates for submitting semiannual reports pursuant to 40 CFR 70.6(a)(3)(iii)(A) or 40 CFR 71.6(a)(3)(iii)(A), the Permittee may submit the first and subsequent compliance reports according to the dates the permitting authority has established instead of according to the dates in Section 63.10031(b)(1) through (4). [40 CFR 63.10031(b)(3) ‐ (5), Minn. R. 7011.0563]

5.6.138 The compliance report must contain the information required in Section 63.10031(c)(1) through (5). (1) The information required by the summary report located


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation in 63.10(e)(3)(vi). (2) The total fuel use by each affected source subject to an emission limit, for each calendar month within the semiannual reporting period, including, but not limited to, a description of the fuel, whether the fuel has received a non‐waste determination by EPA or your basis for concluding that the fuel is not a waste, and the total fuel usage amount with units of measure. (3) Indicate whether the Permittee burned new types of fuel during the reporting period. If the Permittee did burn new types of fuel the Permittee must include the date of the performance test where that fuel was in use. (4) Include the date of the most recent tune‐up for each unit subject to the requirement to conduct a performance tune‐up according to Section 63.10021(e). Include the date of the most recent burner inspection if it was not done every 36 (or 48) months and was delayed until the next scheduled unit shutdown. [40 CFR 63.10031(c)(1) ‐ (4), Minn. R. 7011.0563]

5.6.139 (5) For each instance of startup or shutdown: (i) Include the maximum clean fuel storage capacity and the maximum hourly heat input that can be provided for each clean fuel determined according to the requirements of Section 63.10032(f). (ii) Include the information required to be monitored, collected, or recorded according to the requirements of Section 63.10020(e). (iii) If the Permittee chooses to use CEMS for compliance purposes, include hourly average CEMS values and hourly average flow rates. Use units of milligrams per cubic meter for PM CEMS, micrograms per cubic meter for Hg CEMS, and ppmv for HCl, HF, or SO2 CEMS. Use units of standard cubic meters per hour on a wet basis for flow rates. (iv) If the Permittee chooses to use a separate sorbent trap measurement system for startup or shutdown reporting periods, include hourly average mercury concentration in terms of micrograms per cubic meter. (v) If the Permittee chooses to use a PM CPMS, include hourly average operating parameter values in terms of the operating limit, as well as the operating parameter to PM correlation equation. [40 CFR 63.10031(c)(5), Minn. R. 7011.0563]

5.6.140 For each excess emissions occurring at an affected source


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation where the Permittee is using a CMS to comply with that emission limit or operating limit, the Permittee must include the information required in Section 63.10(e)(3)(v) in the compliance report specified in Section 63.10031(c). [40 CFR 63.10031(d), Minn. R. 7011.0563]

5.6.141 Each affected source that has obtained a Title V operating permit pursuant to part 70 or part 71 of this chapter must report all deviations as defined in this subpart in the semiannual monitoring report required by 40 CFR 70.6(a)(3)(iii)(A) or 40 CFR 71.6(a)(3)(iii)(A). If an affected source submits a compliance report pursuant to Table 8 to subp. UUUUU along with, or as part of, the semiannual monitoring report required by 40 CFR 70.6(a)(3)(iii)(A) or 40 CFR 71.6(a)(3)(iii)(A), and the compliance report includes all required information concerning deviations from any emission limit, operating limit, or work practice requirement in subp. UUUUU, submission of the compliance report satisfies any obligation to report the same deviations in the semiannual monitoring report. Submission of a compliance report does not otherwise affect any obligation the affected source may have to report deviations from permit requirements to the permit authority. [40 CFR 63.10031(e), Minn. R. 7011.0563]

5.6.142 On or after April 16, 2017, within 60 days after the date of completing each performance test, the Permittee must submit the performance test reports required by this subpart to EPA's WebFIRE database by using the Compliance and Emissions Data Reporting Interface (CEDRI) that is accessed through EPA's Central Data Exchange (CDX) (www.epa.gov/cdx). Performance test data must be submitted in the file format generated through use of EPA's Electronic Reporting Tool (ERT) (see http://www.epa.gov/ttn/chief/ert/index.html). Only data collected using those test methods on the ERT Web site are subject to this requirement for submitting reports electronically to WebFIRE. If the Permittee claims that some of the information being submitted for performance tests is confidential business information (CBI), the Permittee must submit a complete ERT file including information claimed to be CBI on a compact disk or other commonly used electronic storage media (including, but not limited to, flash drives) to EPA. The electronic media must be clearly marked as CBI and mailed to U.S. EPA/OAPQS/CORE CBI Office, Attention: WebFIRE Administrator, MD C404‐02, 4930 Old Page Rd., Durham, NC 27703. The same ERT file with the CBI omitted must be submitted to EPA via CDX as described earlier in Section 63.10031(f). At the discretion of the delegated authority, the Permittee must also submit these reports, including the confidential business information, to the delegated authority in the format specified by the delegated authority. [40 CFR 63.10031(f), Minn. R. 7011.0563]


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 5.6.143 On or after April 16, 2017, within 60 days after the date of

completing each CEMS (SO2, PM, HCl, HF, and Hg) performance evaluation test, as defined in Section 63.2 and required by subp. UUUUU, the Permittee must submit the relative accuracy test audit (RATA) data (or, for PM CEMS, RCA and RRA data) required by subp. UUUUU to EPA's WebFIRE database by using CEDRI that is accessed through EPA's CDX (www.epa.gov/cdx). The RATA data shall be submitted in the file format generated through use of EPA's Electronic Reporting Tool (ERT) (http://www.epa.gov/ttn/chief/ert/index.html). Only RATA data compounds listed on the ERT Web site are subject to this requirement. If the Permittee claims that some of the information being submitted for RATAs is confidential business information (CBI), the Permittee shall submit a complete ERT file including information claimed to be CBI on a compact disk or other commonly used electronic storage media (including, but not limited to, flash drives) by registered letter to EPA and the same ERT file with the CBI omitted to EPA via CDX as described earlier in this paragraph. The compact disk or other commonly used electronic storage media shall be clearly marked as CBI and mailed to U.S. EPA/OAPQS/CORE CBI Office, Attention: WebFIRE Administrator, MD C404‐02, 4930 Old Page Rd., Durham, NC 27703. At the discretion of the delegated authority, owners or operators shall also submit these RATAs to the delegated authority in the format specified by the delegated authority. Owners or operators shall submit calibration error testing, drift checks, and other information required in the performance evaluation as described in Section 63.2 and as required in this chapter. [40 CFR 63.10031(f)(1), Minn. R. 7011.0563]

5.6.144 On or after April 16, 2017, for a PM CEMS, PM CPMS, or approved alternative monitoring using a HAP metals CEMS, within 60 days after the reporting periods ending on March 31st, June 30th, September 30th, and December 31st, the Permittee must submit quarterly reports to EPA's WebFIRE database by using the CEDRI that is accessed through EPA's CDX (www.epa.gov/cdx). The Permittee must use the appropriate electronic reporting form in CEDRI or provide an alternate electronic file consistent with EPA's reporting form output format. For each reporting period, the quarterly reports must include all of the calculated 30‐boiler operating day rolling average values derived from the CEMS and PM CPMS. [40 CFR 63.10031(f)(2), Minn. R. 7011.0563]

5.6.145 (3) Reports for an SO2 CEMS, a Hg CEMS or sorbent trap monitoring system, an HCl or HF CEMS, and any supporting monitors for such systems (such as a diluent or moisture monitor) shall be submitted using the ECMPS Client Tool, as provided for in Appendices A and B to subp. UUUUU and


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation Section 63.10021(f). (4) On or after April 16, 2017, submit the compliance reports required under Section 63.10031(c) and (d) and the notification of compliance status required under Section 63.10030(e) to EPA's WebFIRE database by using the CEDRI that is accessed through EPA's CDX (www.epa.gov/cdx). The Permittee must use the appropriate electronic reporting form in CEDRI or provide an alternate electronic file consistent with EPA's reporting form output format. (5) All reports required by subp. UUUUU not subject to the requirements in Section must be sent to the Administrator at the appropriate address listed in Section 63.13. If acceptable to both the Administrator and the Permittee, these reports may be submitted on electronic media. The Administrator retains the right to require submittal of reports subject to 63.10031(f) and (f)(1) through (4) in paper format. [40 CFR 63.10031(f)(3) ‐ (5), Minn. R. 7011.0563]

5.6.146 (6) Prior to April 16, 2017, all reports subject to electronic submittal in Section 63.10031(f) introductory text, (f)(1), (2), and (4) shall be submitted to the EPA at the frequency specified in those paragraphs in electronic portable document format (PDF) using the ECMPS Client Tool. Each PDF version of a submitted report must include sufficient information to assess compliance and to demonstrate that the testing was done properly. The following data elements must be entered into the ECMPS Client Tool at the time of submission of each PDF file: (i) The facility name, physical address, mailing address (if different from the physical address), and county; (ii) The ORIS code (or equivalent ID number assigned by EPA's Clean Air Markets Division (CAMD)) and the Facility Registry System (FRS) ID; (iii) The EGU (or EGUs) to which the report applies. Report the EGU IDs as they appear in the CAMD Business System; (iv) If any of the EGUs in Section 63.10031(f)(6)(iii) share a common stack, indicate which EGUs share the stack. If emissions data are monitored and reported at the common stack according to part 75 of this chapter, report the ID number of the common stack as it is represented in the electronic monitoring plan required under Section 75.53 of this chapter; (v) If any of the EGUs described in Section 63.10031(f)(6)(iii)


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation are in an averaging plan under Section 63.10009, indicate which EGUs are in the plan and whether it is a 30‐ or 90‐day averaging plan; (vi) The identification of each emission point to which the report applies. An "emission point" is a point at which source effluent is released to the atmosphere, and is either a dedicated stack that serves one of the EGUs identified in Section 63.10031(f)(6)(iii) or a common stack that serves two or more of those EGUs. To identify an emission point, associate it with the EGU or stack ID in the CAMD Business system or the electronic monitoring plan (e.g., "Unit 2 stack," "common stack CS001," or "multiple stack MS001"); (vii) The rule citation (e.g., Section 63.10031(f)(1), Section 63.10031(f)(2), etc.) for which the report is showing compliance; (viii) The pollutant(s) being addressed in the report; (ix) The reporting period being covered by the report (if applicable); (x) The relevant test method that was performed for a performance test (if applicable); (xi) The date the performance test was conducted (if applicable); and (xii) The responsible official's name, title, and phone number. [40 CFR 63.10031(f)(6), Minn. R. 7011.0563]

5.6.147 If the Permittee's affected facility had a malfunction during the reporting period, the compliance report must include the number, duration, and a brief description for each type of malfunction which occurred during the reporting period and which caused or may have caused any applicable emission limitation to be exceeded. [40 CFR 63.10031(g), Minn. R. 7011.0563]

5.6.148 The Permittee must keep records according to Section 63.10032(a)(1) and (2). If the Permittee is required to (or elects to) continuously monitor Hg and/or HCl and/or HF emissions, the Permittee must also keep the records required under appendix A and/or appendix B to subp. UUUUU. (1) A copy of each notification and report the Permittee submitted to comply with subp. UUUUU, including all documentation supporting any Initial Notification or Notification of Compliance Status or semiannual compliance report the Permittee submitted, according to the


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation requirements in Section 63.10(b)(2)(xiv). (2) Records of performance stack tests, fuel analyses, or other compliance demonstrations and performance evaluations, as required in Section 63.10(b)(2)(viii). [40 CFR 63.10032(a), Minn. R. 7011.0563]

5.6.149 (b) For each CEMS and CPMS, the Permittee must keep records according to Section 63.10032(b)(1) through (4). (1) Records described in Section 63.10(b)(2)(vi) through (xi). (2) Previous (i.e., superseded) versions of the performance evaluation plan as required in Section 63.8(d)(3). (3) Request for alternatives to relative accuracy test for CEMS as required in Section 63.8(f)(6)(i). (4) Records of the date and time that each deviation started and stopped, and whether the deviation occurred during a period of startup, shutdown, or malfunction or during another period. [40 CFR 63.10032(b)(1) ‐ (4), Minn. R. 7011.0563]

5.6.150 The Permittee must keep the records required in Table 7 to subp. UUUUU including records of all monitoring data and calculated averages for applicable PM CPMS operating limits to show continuous compliance with each applicable emission limit and operating limit. [40 CFR 63.10032(c), Minn. R. 7011.0563]

5.6.151 For each EGU subject to an emission limit, the Permittee must also keep the records in Section 63.10032(d)(1) through (3). (1) The Permittee must keep records of monthly fuel use by each EGU, including the type(s) of fuel and amount(s) used. (2) If the Permittee combusts non‐hazardous secondary materials that have been determined not to be solid waste pursuant to 40 CFR 241.3(b)(1), the Permittee must keep a record which documents how the secondary material meets each of the legitimacy criteria. If the Permittee combusts a fuel that has been processed from a discarded non‐hazardous secondary material pursuant to 40 CFR 241.3(b)(2), the Permittee must keep records as to how the operations that produced the fuel satisfies the definition of processing in 40 CFR 241.2. If the fuel received a non‐waste determination pursuant to the petition process submitted under 40 CFR 241.3(c), the Permittee must keep a record which documents how the fuel satisfies the requirements of the petition process. (3) For an EGU that qualifies as an LEE under Section 63.10005(h), the Permittee must keep annual records that


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation document that its emissions in the previous stack test(s) continue to qualify the unit for LEE status for an applicable pollutant, and document that there was no change in source operations including fuel composition and operation of air pollution control equipment that would cause emissions of the pollutant to increase within the past year. [40 CFR 63.10032(d), Minn. R. 7011.0563]

5.6.152 If the Permittee elects to average emissions consistent with Section 63.10009, the Permittee must additionally keep a copy of the emissions averaging implementation plan required in Section 63.10009(g), all calculations required under Section 63.10009, including daily records of heat input or steam generation, as applicable, and monitoring records consistent with Section 63.10022. [40 CFR 63.10032(e), Minn. R. 7011.0563]

5.6.153 Regarding startup periods or shutdown periods, the Permittee must keep records of: (1) The occurrence and duration of each startup or shutdown; (2) The determination of the maximum clean fuel capacity for each EGU; (3) The determination of the maximum hourly clean fuel heat input and of the hourly clean fuel heat input for each EGU; and (4) The information required in Section 63.10020(e). [40 CFR 63.10032(f)(1) ‐ (4), Minn. R. 7011.0563]

5.6.154 The Permittee must keep records of the occurrence and duration of each malfunction of an operation (i.e., process equipment) or the air pollution control and monitoring equipment. [40 CFR 63.10032(g), Minn. R. 7011.0563]

5.6.155 The Permittee must keep records of actions taken during periods of malfunction to minimize emissions in accordance with Section 63.10000(b), including corrective actions to restore malfunctioning process and air pollution control and monitoring equipment to its normal or usual manner of operation. [40 CFR 63.10032(h), Minn. R. 7011.0563]

5.6.156 The Permittee must keep records of the type(s) and amount(s) of fuel used during each startup or shutdown. [40 CFR 63.10032(i), Minn. R. 7011.0563]

5.6.157 (a) The Permittee's records must be in a form suitable and readily available for expeditious review, according to Section 63.10(b)(1). (b) As specified in Section 63.10(b)(1), the Permittee must keep each record for 5 years following the date of each occurrence, measurement, maintenance, corrective action, report, or record.


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation (c) The Permittee must keep each record on site for at least 2 years after the date of each occurrence, measurement, maintenance, corrective action, report, or record, according to Section 63.10(b)(1). The Permittee can keep the records off site for the remaining 3 years. [40 CFR 63.10033(a) ‐ (c), Minn. R. 7011.0563]

5.6.158 Terms used in Part 63, Subpart UUUUU are defined in the Clean Air Act, in 40 CFR Section 63.2 (the General Provisions), and in 40 CFR Section 63.10042. [40 CFR 63.10042, Minn. R. 7011.0563]

5.6.159 PART 63, SUBPART A GENERAL PROVISIONS Circumvention. The Permittee shall not build, erect, install, or use any article, machine, equipment, or process to conceal an emission that would otherwise constitute noncompliance with a relevant standard. Such concealment includes, but is not limited to‐ (1) The use of diluents to achieve compliance with a relevant standard based on the concentration of a pollutant in the effluent discharged to the atmosphere; (2) The use of gaseous diluents to achieve compliance with a relevant standard for visible emissions. [40 CFR 63.4(b), Minn. R. 7011.7000]

5.6.160 After the February 16, 2012 effective date of pt. 63, subp. UUUUU, equipment added (or a process change) to an affected source that is within the scope of the definition of affected source under subp. UUUUU must be considered part of the affected source and subject to all provisions of subp. UUUUU. [40 CFR 63.5(b)(6), Minn. R. 7011.7000]

5.6.161 Methods for determining compliance. (i) The Administrator will determine compliance with nonopacity emission standards in pt. 63, subp. UUUUU based on the results of performance tests conducted according to the procedures in Section 63.7, unless otherwise specified in pt. 63, subp. UUUUU. (ii) The Administrator will determine compliance with nonopacity emission standards in pt. 63, subp. UUUUU by evaluation of the Permittee's conformance with operation and maintenance requirements, including the evaluation of monitoring data as specified in pt. 63, subp. UUUUU. (iii) If an affected source conducts performance testing at startup to obtain an operating permit in the State in which the source is located, the results of such testing may be used to demonstrate compliance with a relevant standard if‐


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation (A) The performance test was conducted within a reasonable amount of time before the initial performance test required by pt. 63, subp. UUUUU; (B) The performance test was conducted under representative operating conditions for the source; (C) The performance test was conducted and the resulting data were reduced using EPA‐approved test methods and procedures, as specified in Section 63.7(e), except requirements at Section 63.7(e)(1) are replaced by requirements at Section 63.10007; and (D) The performance test was appropriately quality‐assured, as specified in Section 63.7(c). (iv) The Administrator will determine compliance with design, equipment, work practice, or operational emission standards in this part by review of records, inspection of the source, and other procedures specified in pt. 63, subp. UUUUU. (v) The Administrator will determine compliance with design, equipment, work practice, or operational emission standards in pt. 63 by evaluation of the Permittee's conformance with operation and maintenance requirements, as specified in pt. 63, subp. UUUUU. [40 CFR 63.6(f)(2), Minn. R. 7011.7000]

5.6.162 Finding of compliance. The Administrator will make a finding concerning the Permittee's affected source's compliance with a non‐opacity emission standard, as specified in Section 63.6(f)(2), upon obtaining all the compliance information required by pt. 63, subp. UUUUU (including the written reports of performance test results, monitoring results, and other information, if applicable). [40 CFR 63.6(f)(3), Minn. R. 7011.7000]

5.6.163 The Permittee may establish the use of an alternative non‐opacity emission standard by following the procedure specified in 40 CFR Section 63.6(g). [40 CFR 63.6(g), Minn. R. 7011.7000]

5.6.164 Except as provided in Section 63.7(a)(4), and unless a waiver of performance testing is obtained under Section 63.7 or the conditions of Section 63.7(c)(3)(ii)(B) apply, the Permittee must perform tests required by pt. 63, subp. UUUUU no later than 180 days after April 16, 2015. This requirement was completed and the Notice of Compliance Status was submitted to the EPA Emissions Collection and Monitoring Plan System on October 13, 2015. [40 CFR 63.7(a)(2), Minn. R. 7017.2015]

5.6.165 Notification of performance test. (1) The Permittee must notify


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation the Administrator in writing of its intention to conduct a performance test at least 60 calendar days before the performance test is initially scheduled to begin to allow the Administrator, upon request, to review an approve the site‐specific test plan required under Section 63.7(c) and to have an observer present during the test. (2) In the event the Permittee is unable to conduct the performance test on the date specified in the notification requirement specified in Section 63.7(b)(1) due to unforeseeable circumstances beyond the Permittee's control, the Permittee must notify the Administrator as soon as practicable and without delay prior to the scheduled performance test date and specify the date when the performance test is rescheduled. This notification of delay in conducting the performance test shall not relieve the Permittee of legal responsibility for compliance with any other applicable provisions of pt. 63 or with any other applicable Federal, State, or local requirement, nor will it prevent the Administrator from implementing or enforcing this part or taking any other action under the Act. [40 CFR 63.7(b)(1) & (2), Minn. R. 7017.2015]

5.6.166 Submission of site‐specific test plan. Before conducting a required performance test, the Permittee shall develop and, if requested by the Commissioner or the Administrator, shall submit a site‐specific test plan for approval in accordance with the requirements of 40 CFR Section 63.7(c)(2). [40 CFR 63.7(c)(2), Minn. R. 7017.2015]

5.6.167 Approval of site‐specific test plan. The Administrator will notify the Permittee of approval or intention to deny approval of the site‐specific test plan (if review of the site‐specific test plan is requested) within 30 calendar days after receipt of the original plan and within 30 calendar days after receipt of any supplementary information. Test plan disapproval or lack of approval/disapproval is subject to additional requirements at Section 63.7(c)(3). [40 CFR 63.7(c)(3), Minn. R. 7017.2015]

5.6.168 Performance testing facilities. The Permittee, at the request of the Commissioner or the Administrator, shall provide performance testing facilities as specified in 40 CFR Section 63.7(d). [40 CFR 63.7(d), Minn. R. 7017.2015]

5.6.169 Conduct of performance tests. 1) Performance tests shall be conducted under conditions specified by the Administrator based on representative performance of the affected source. Operations during periods of startup, shutdown, and malfunction shall not constitute representative conditions for the purpose of a performance test. 2) Performance tests shall be conducted and data shall be reduced in accordance with the test methods and procedures


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation set forth in 40 CFR Section 63.7(e), in each relevant standard, and, if required, in applicable appendices of 40 CFR parts 51, 60, 61. The Commissioner has delegation to approve a minor or intermediate modification (if validated by Method 301) to a reference method or specified monitoring procedure as allowed for in 40 CFR Section 63.7(e)(2)(i) and (ii). [40 CFR 63.7(e)(1) & (2), Minn. R. 7017.2015]

5.6.170 Unless otherwise specified in a relevant standard or test method, each performance test shall consist of three separate runs using the applicable test method. Each run shall be conducted for the time and under the conditions specified in the relevant standard. For the purpose of determining compliance with a relevant standard, the arithmetic mean of the results of the three runs shall apply, unless otherwise approved in accordance with provisions of Section 63.7(e)(3). [40 CFR 63.7(e)(3), Minn. R. 7017.2015]

5.6.171 Data analysis, recordkeeping, and reporting. Unless otherwise specified in a relevant standard or test method, or as otherwise approved by the Commissioner or Administrator in writing, results of a performance test shall include the analysis of samples, determination of emissions, and raw data. A performance test is "completed" when field sample collection is terminated. The Permittee shall report the results of the performance test to the Commissioner or Administrator before the close of business on the 60th day following the completion of the performance test, unless specified otherwise in a relevant standard or as approved otherwise in writing. The results of the performance test shall be submitted as part of the notification of compliance status required under Section 63.9(h) to the appropriate permitting authority. [40 CFR 63.7(g), Minn. R. 7011.2015]

5.6.172 Waiver of performance tests. Until a waiver of a performance testing requirement has been granted by the Commissioner or the Administrator under Section 63.7(h), the Permittee remains subject to the requirements of Section 63.7(h). Additional procedures and requirements for performance test waivers are specified in Section 63.7(h). [40 CFR 63.7(h), Minn. R. 7017.2015]

5.6.173 For the purposes of pt. 63, all CMS required under relevant standards shall be subject to the provisions of Section 63.8 upon promulgation of performance specifications for CMS as specified in the relevant standard or otherwise by the Administrator. [40 CFR 63.8(a)(2), Minn. R. 7017.1010]

5.6.174 Conduct of monitoring. (1) Monitoring shall be conducted as set forth in Section 63.8 and the relevant standard(s) unless the Administrator approves otherwise according to Section 63.8(b)(1). [40 CFR 63.8(b)(1), Minn. R. 7017.1010]

5.6.175 Operation and maintenance of continuous monitoring systems.


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation (1) The Permittee shall maintain and operate each CMS as specified in Section 63.8, or in a relevant standard, and in a manner consistent with good air pollution control practices. (ii) The owner or operator must keep the necessary parts for routine repairs of the affected CMS equipment readily available. (2)(i) All CMS must be installed such that representative measures of emissions or process parameters from the affected source are obtained. In addition, CEMS must be located according to procedures contained in the applicable performance specification(s). (ii) Unless subp. UUUUU states otherwise, the Permittee must ensure the read out (that portion of the CMS that provides a visual display or record), or other indication of operation, from any CMS required for compliance with the emission standard is readily accessible on site for operational control or inspection by the operator of the equipment. (3) All CMS shall be installed, operational, and the data verified as specified in subp. UUUUU either prior to or in conjunction with conducting performance tests under Section 63.7. Verification of operational status shall, at a minimum, include completion of the manufacturer's written specifications or recommendations for installation, operation, and calibration of the system. (4) Except for system breakdowns, out‐of‐control periods, repairs, maintenance periods, calibration checks, and zero (low‐level) and high‐level calibration drift adjustments, all CMS, including COMS and CEMS, shall be in continuous operation and shall meet minimum frequency of operation requirements as follows: (i) All COMS shall complete a minimum of one cycle of sampling and analyzing for each successive 10‐second period and one cycle of data recording for each successive 6‐minute period. (ii) All CEMS for measuring emissions other than opacity shall complete a minimum of one cycle of operation (sampling, analyzing, and data recording) for each successive 15‐minute period. (5) Unless otherwise approved by the Administrator, minimum procedures for COMS shall include a method for


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation producing a simulated zero opacity condition and an upscale (high‐level) opacity condition using a certified neutral density filter or other related technique to produce a known obscuration of the light beam. Such procedures shall provide a system check of all the analyzer's internal optical surfaces and all electronic circuitry, including the lamp and photodetector assembly normally used in the measurement of opacity. [40 CFR 63.8(c)(1) ‐ (5), Minn. R. 7017.1010]

5.6.176 For a CMS that is not a CPMS, which is installed in accordance with the provisions of this part and the applicable CMS performance specification(s), the Permittee must check the zero (low‐level) and high‐level calibration drifts at least once daily in accordance with the written procedure specified in the performance evaluation plan developed under Section 63.8(e)(3)(i) and (ii). The zero (low‐level) and high‐level calibration drifts must be adjusted, at a minimum, whenever the 24‐hour zero (low‐level) drift exceeds two times the limits of the applicable performance specification(s) specified in the relevant standard. The system shall allow the amount of excess zero (low‐level) and high‐level drift measured at the 24‐hour interval checks to be recorded and quantified whenever specified. The CPMS must be calibrated prior to use for the purposes of complying with this section. The CPMS must be checked daily for indication that the system is responding. If the CPMS system includes an internal system check, results must be recorded and checked daily for proper operation. [40 CFR 63.8(c)(6), Minn. R. 7017.1010]

5.6.177 (i) A CMS is out of control if‐ (A) The zero (low‐level), mid‐level (if applicable), or high‐level calibration drift (CD) exceeds two times the applicable CD specification in the applicable performance specification or in the relevant standard; or (B) The CMS fails a performance test audit (e.g., cylinder gas audit), relative accuracy audit, relative accuracy test audit, or linearity test audit. (ii) When the CMS is out of control, the Permittee shall take the necessary corrective action and shall repeat all necessary tests which indicate that the system is out of control. The Permittee shall take corrective action and conduct retesting until the performance requirements are below the applicable limits. The beginning of the out‐of‐control period is the hour the Permittee conducts a performance check (e.g., calibration drift) that indicates an exceedance of the performance requirements established under pt. 63. The end of the out‐of‐control period is the hour following the completion of corrective action and successful demonstration that the


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation system is within the allowable limits. During the period the CMS is out of control, recorded data shall not be used in data averages and calculations, or to meet any data availability requirement established under pt. 63. [40 CFR 63.8(c)(7), Minn. R. 7017.1010]

5.6.178 For a CMS that is out of control as defined in Section 63.8(c)(7), the Permittee shall submit all information concerning out‐of‐control periods, including start and end dates and hours and descriptions of corrective actions taken, in the excess emissions and continuous monitoring system performance report required in Section 63.10(e)(3). [40 CFR 63.8(c)(8), Minn. R. 7017.1010]

5.6.179 Quality control program. (1) The results of the quality control program required in Section 63.8(d) will be considered by the Administrator when he/she determines the validity of monitoring data. (2) When the Permittee in the operation of an affected source is required to use a CMS and is subject to the monitoring requirements of Section 63.8(d) and a relevant standard, the Permittee shall develop and implement a CMS quality control program. As part of the quality control program, the Permittee shall develop and submit to the Administrator for approval upon request a site‐specific performance evaluation test plan for the CMS performance evaluation required in Section 63.8(e)(3)(i), according to the procedures specified in Section 63.8(e). In addition, each quality control program shall include, at a minimum, a written protocol that describes procedures for each of the following operations: (i) Initial and any subsequent calibration of the CMS; (ii) Determination and adjustment of the calibration drift of the CMS; (iii) Preventive maintenance of the CMS, including spare parts inventory; (iv) Data recording, calculations, and reporting; (v) Accuracy audit procedures, including sampling and analysis methods; and (vi) Program of corrective action for a malfunctioning CMS. (3) The Permittee shall keep these written procedures on record for the life of the affected source or until the affected source is no longer subject to the provisions of this part, to be made available for inspection, upon request, by the


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation Administrator. If the performance evaluation plan is revised, the owner or operator shall keep previous (i.e., superseded) versions of the performance evaluation plan on record to be made available for inspection, upon request, by the Administrator, for a period of 5 years after each revision to the plan. [40 CFR 63.8(d), Minn. R. 7017.1010]

5.6.180 Performance evaluation of continuous monitoring systems‐(1) General. When required by a relevant standard, and at any other time the Administrator may require under section 114 of the Act, the Permittee shall conduct a performance evaluation of the CMS on the monitored source. Such performance evaluation shall be conducted according to the applicable specifications and procedures described in Section 63.8 or in pt. 63, subp. UUUUU. (2) Notification of performance evaluation. The Permittee shall notify the Administrator in writing of the date of the performance evaluation simultaneously with the notification of the performance test date required under Section 63.7(b) or at least 60 days prior to the date the performance evaluation is scheduled to begin if no performance test is required. [40 CFR 63.8(e)(1) & (2), Minn. R. 7017.1010]

5.6.181 (i) Submission of site‐specific performance evaluation test plan. Before conducting a required CMS performance evaluation, the Permittee shall develop and submit a site‐specific performance evaluation test plan to the Administrator for approval upon request. The performance evaluation test plan shall include the evaluation program objectives, an evaluation program summary, the performance evaluation schedule, data quality objectives, and both an internal and external QA program. Data quality objectives are the pre‐evaluation expectations of precision, accuracy, and completeness of data. (ii) The internal QA program shall include, at a minimum, the activities planned by routine operators and analysts to provide an assessment of CMS performance. The external QA program shall include, at a minimum, systems audits that include the opportunity for on‐site evaluation by the Administrator of instrument calibration, data validation, sample logging, and documentation of quality control data and field maintenance activities. (iii) The Permittee source shall submit the site‐specific performance evaluation test plan to the Administrator (if requested) at least 60 days before the performance test or performance evaluation is scheduled to begin, or on a mutually agreed upon date, and review and approval of the performance evaluation test plan by the Administrator will


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation occur with the review and approval of the site‐specific test plan (if review of the site‐specific test plan is requested). (iv) The Administrator may request additional relevant information after the submittal of a site‐specific performance evaluation test plan. [40 CFR 63.8(e)(3)(i) ‐ (iv), Minn. R. 7017.1010]

5.6.182 (v) In the event that the Administrator fails to approve or disapprove the site‐specific performance evaluation test plan within the time period specified in Section 63.7(c)(3), the following conditions shall apply: (A) If the Permittee intends to demonstrate compliance using the monitoring method(s) specified in pt. 63, subp. UUUUU, the Permittee shall conduct the performance evaluation within the time specified in pt. 63, subp. A using the specified method(s); (B) If the Permittee intends to demonstrate compliance by using an alternative to a monitoring method specified in subp. UUUUU, the Permittee shall refrain from conducting the performance evaluation until the Administrator approves the use of the alternative method. If the Administrator does not approve the use of the alternative method within 30 days before the performance evaluation is scheduled to begin, the performance evaluation deadlines specified in Section 63.8(e)(4) may be extended such that the Permittee shall conduct the performance evaluation within 60 calendar days after the Administrator approves the use of the alternative method. Notwithstanding the requirements in the preceding two sentences, the Permittee may proceed to conduct the performance evaluation as required in this section (without the Administrator's prior approval of the site‐specific performance evaluation test plan) if he/she subsequently chooses to use the specified monitoring method(s) instead of an alternative. [40 CFR 63.8(e)(3)(v), Minn. R. 7017.1010]

5.6.183 (vi) Neither the submission of a site‐specific performance evaluation test plan for approval, nor the Administrator's approval or disapproval of a plan, nor the Administrator's failure to approve or disapprove a plan in a timely manner shall‐ (A) Relieve the Permittee of legal responsibility for compliance with any applicable provisions of part 63 or with any other applicable Federal, State, or local requirement; or (B) Prevent the Administrator from implementing or enforcing part 63 or taking any other action under the Act. [40 CFR 63.8(e)(3)(vi), Minn. R. 7017.1010]


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 5.6.184 Conduct of performance evaluation and performance

evaluation dates. The Permittee shall conduct a performance evaluation of a required CMS during any performance test required under Section 63.7 in accordance with the applicable performance specification as specified in subp. UUUUU. If a performance test is not required, or the requirement for a performance test has been waived under Section 63.7(h), the Permittee shall conduct the performance evaluation not later than 180 days after the appropriate compliance date for the affected source, as specified in Section 63.7(a), or as otherwise specified in subp. UUUUU. [40 CFR 63.8(e)(4), Minn. R. 7017.1010]

5.6.185 Reporting performance evaluation results. (i) The Permittee shall furnish the Administrator a copy of a written report of the results of the performance evaluation simultaneously with the results of the performance test required under Section 63.7 or within 60 days of completion of the performance evaluation if no test is required, unless otherwise specified in pt. 63, subp. UUUUU. The Administrator may request that the owner or operator submit the raw data from a performance evaluation in the report of the performance evaluation results. [40 CFR 63.8(e)(5)(i), Minn. R. 7017.1010]

5.6.186 Use of an alternative monitoring method. Until permission to use an alternative monitoring procedure has been granted by the Administrator under 40 CFR Sections 63.8(f)(1)‐(6), as appropriate, the Permittee remains subject to the requirements of 40 CFR Section 63.8 and pt. 63, subp. UUUUU. Alternative monitoring requests and approvals shall meet the requirements of Section 63.8(f)(1)‐(6). [40 CFR 63.8(f), Minn. R. 7017.1010]

5.6.187 Reduction of monitoring data. The Permittee must reduce monitoring data as specified in 40 CFR Section 63.8(g)(1)‐(5). [40 CFR 63.8(g), Minn. R. 7017.1010]

5.6.188 Initial notifications. (2) The Permittee shall notify the Administrator in writing that the source is subject to subp. UUUUU. The notification, which shall be submitted not later than 120 calendar days after the February 16, 2012 effective date of subp. UUUUU (or within 120 calendar days after the source becomes subject to subp. UUUUU), shall provide the following information: (i) The name and address of the Permittee; (ii) The address (i.e., physical location) of the affected source; (iii) An identification of the relevant standard (subp. UUUUU), or other requirement, that is the basis of the notification and the source's compliance date;


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation (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 subp. UUUUU 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 63.9(b)(2), Minn. R. 7019.0100]

5.6.189 Notification of performance test. The Permittee shall notify the Administrator in writing of its intention to conduct a performance test at least 60 calendar days before the performance test is scheduled to begin to allow the Administrator to review and approve the site‐specific test plan required under Section 63.7(c), if requested by the Administrator, and to have an observer present during the test. [40 CFR 63.9(e), Minn. R. 7019.0100]

5.6.190 Additional notification requirements for sources with continuous monitoring systems. For any CMS required by subp. UUUUU, the Permittee shall furnish the Administrator written notification as follows: (1) A notification of the date the CMS performance evaluation under Section 63.8(e) is scheduled to begin, submitted simultaneously with the notification of the performance test date required under Section 63.7(b). If no performance test is required, or if the requirement to conduct a performance test has been waived for an affected source under Section 63.7(h), the Permittee shall notify the Administrator in writing of the date of the performance evaluation at least 60 calendar days before the evaluation is scheduled to begin; and, (3) A notification that the criterion necessary to continue use of an alternative to relative accuracy testing, as provided by Section 63.8(f)(6), has been exceeded. The notification shall be delivered or postmarked not later than 10 days after the occurrence of such exceedance, and it shall include a description of the nature and cause of the increased emissions. [40 CFR 63.9(g)(1) & (3), Minn. R. 7019.0100]

5.6.191 Notification of compliance status. Each time a notification of compliance status is required under 40 CFR pt. 63, subp. A, the Permittee shall submit to the Commissioner a notification of compliance status containing the information required by 40 CFR Section 63.9(h), signed by the responsible official who shall certify its accuracy, attesting to whether the source has complied with the relevant standard. The notification must be sent by the 60th day following the


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation completion of the relevant compliance demonstration activity specified in pt. 63, subp. UUUUU. Notifications may be combined as long as the due date requirement for each notification is met. [40 CFR 63.9(h), Minn. R. 7019.0100]

5.6.192 Change in information already provided. Any change in the information already provided under Section 63.9 shall be provided to the Administrator in writing within 15 calendar days after the change. [40 CFR 63.9(j), Minn. R. 7019.0100]

5.6.193 The Permittee shall submit reports to the Commissioner and shall send a copy of each report to the Administrator. [40 CFR 63.10(a), Minn. R. 7019.0100]

5.6.194 General recordkeeping requirements. (1) The Permittee shall maintain files of all information (including all reports and notifications) required by pt. 63 recorded in a form suitable and readily available for expeditious inspection and review. The files shall be retained for at least 5 years following the date of each occurrence, measurement, maintenance, corrective action, report, or record. At a minimum, the most recent 2 years of data shall be retained on site. The remaining 3 years of data may be retained off site. Such files may be maintained on microfilm, on a computer, on computer floppy disks, on magnetic tape disks, or on microfiche. [40 CFR 63.10(b), Minn. R. 7019.0100, subp. 2(B)]

5.6.195 (2) The Permittee shall maintain relevant records for such source of‐ (iii) All required maintenance performed on the air pollution control and monitoring equipment; (vi) Each period during which a CMS is malfunctioning or inoperative (including out‐of‐control periods); (vii) All required measurements needed to demonstrate compliance with a relevant standard (including, but not limited to, 15‐minute averages of CMS data, raw performance testing measurements, and raw performance evaluation measurements, that support data that the source is required to report); (A) This paragraph applies to the Permittee if it is required to install a continuous emissions monitoring system (CEMS) where the CEMS installed is automated, and where the calculated data averages do not exclude periods of CEMS breakdown or malfunction. An automated CEMS records and reduces the measured data to the form of the pollutant emission standard through the use of a computerized data acquisition system. In lieu of maintaining a file of all CEMS subhourly measurements as required under Section 63.10(b)(2)(vii), the Permittee shall retain the most recent


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation consecutive three averaging periods of subhourly measurements and a file that contains a hard copy of the data acquisition system algorithm used to reduce the measured data into the reportable form of the standard. (B) This paragraph applies to the Permittee if it is required to install a CEMS where the measured data is manually reduced to obtain the reportable form of the standard, and where the calculated data averages do not exclude periods of CEMS breakdown or malfunction. In lieu of maintaining a file of all CEMS subhourly measurements as required under Section 63.10(b)(2)(vii), the Permittee shall retain all subhourly measurements for the most recent reporting period. The subhourly measurements shall be retained for 120 days from the date of the most recent summary or excess emission report submitted to the Administrator. (C) The Administrator or delegated authority, upon notification to the source, may require the Permittee to maintain all measurements as required by Section 63.10(b)(2)(vii), if the Administrator or the delegated authority determines these records are required to more accurately assess the compliance status of the affected source. [40 CFR 63.10(b)(2)(iii), (vi), & (vii), Minn. R. 7019.0100, subp. 2(B)]

5.6.196 The Permittee shall maintain relevant records for the affected source of‐ (viii) All results of performance tests and CMS performance evaluations; (ix) All measurements as may be necessary to determine the conditions of performance tests and performance evaluations; (x) All CMS calibration checks; (xi) All adjustments and maintenance performed on CMS; (xii) Any information demonstrating whether a source is meeting the requirements for a waiver of recordkeeping or reporting requirements under this part, if the source has been granted a waiver under Section 60.10(f); (xiii) All emission levels relative to the criterion for obtaining permission to use an alternative to the relative accuracy test, if the source has been granted such permission under Section 63.8(f)(6); and (xiv) All documentation supporting initial notifications and notifications of compliance status under Section 63.9. [40 CFR


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 63.10(b)(2)(viii) ‐ (xiv), Minn. R. 7019.0100, subp. 2(B)]

5.6.197 Additional recordkeeping requirements for sources with continuous monitoring systems. In addition to complying with the requirements specified in Section 63.10(b)(1) and (b)(2), the Permittee shall maintain records for the affected source of‐ (1) All required CMS measurements (including monitoring data recorded during unavoidable CMS breakdowns and out‐of‐control periods); (2)‐(4) [Reserved] (5) The date and time identifying each period during which the CMS was inoperative except for zero (low‐level) and high‐level checks; (6) The date and time identifying each period during which the CMS was out of control, as defined in Section 63.8(c)(7); (7) The specific identification (i.e., the date and time of commencement and completion) of each period of excess emissions and parameter monitoring exceedances, as defined in the relevant standard(s), that occurs during startups, shutdowns, and malfunctions of the affected source; (8) The specific identification (i.e., the date and time of commencement and completion) of each time period of excess emissions and parameter monitoring exceedances, as defined in the relevant standard(s), that occurs during periods other than startups, shutdowns, and malfunctions of the affected source; (9) [Reserved] (12) The nature of the repairs or adjustments to the CMS that was inoperative or out of control; (13) The total process operating time during the reporting period; and (14) All procedures that are part of a quality control program developed and implemented for CMS under Section 63.8(d). [40 CFR 63.10(c)(1) ‐ (9), 40 CFR 63.10(c)(12) ‐ (14), Minn. R. 7019.0100]

5.6.198 General reporting requirements. (1) Notwithstanding the requirements in Section 63.10(d) and (e), and except as provided in Section 63.16, the Permittee shall submit reports to the Administrator in accordance with the reporting


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation requirements in pt. 63, subp. UUUUU. (2) Reporting results of performance tests. The Permittee shall report the results of a required performance test to the appropriate permitting authority. The Permittee shall report the results of the performance test to the Administrator (or the State with an approved permit program) before the close of business on the 60th day following the completion of the performance test, unless specified otherwise in pt. 63, subp. UUUUU or as approved otherwise in writing by the Administrator. The results of the performance test shall be submitted as part of the notification of compliance status required under Section 63.9(h). [40 CFR 63.10(d)(1) & (2), Minn. R. 7019.0100]

5.6.199 Reporting results of continuous monitoring system performance evaluations. (i) If the Permittee is required to install a CMS by pt. 63, subp. UUUUU, the Permittee shall furnish the Administrator a copy of a written report of the results of the CMS performance evaluation, as required under Section 63.8(e), simultaneously with the results of the performance test required under Section 63.7, unless otherwise specified in subp. UUUUU. [40 CFR 63.10(e)(2)(i), Minn. R. 7019.0100]

5.6.200 Excess emissions and continuous monitoring system performance report and summary report. (i) Excess emissions and parameter monitoring exceedances are defined in pt. 63, subp. UUUUU. If the Permittee is required to install a CMS by subp. UUUUU, the Permittee shall submit an excess emissions and continuous monitoring system performance report and/or a summary report to the Administrator semiannually, except when‐ (A) More frequent reporting is specifically required by subp. UUUUU; (B) The Administrator determines on a case‐by‐case basis that more frequent reporting is necessary to accurately assess the compliance status of the source; or (C) [Reserved] (D) The affected source is complying with the Performance Track Provisions of Section 63.16 which allows less frequent reporting. [40 CFR 63.10(e)(3)(i), Minn. R. 7019.0100]

5.6.201 Request to reduce frequency of excess emissions and continuous monitoring system performance reports. Notwithstanding the frequency of reporting requirements specified in Section 63.10(e)(3)(i), the Permittee may reduce the subp. UUUUU quarterly (or more frequent if applicable)


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation reporting of excess emissions and continuous monitoring system performance (and summary) reports to semiannual if the following conditions are met: (A) For 1 full year (e.g., 4 quarterly or 12 monthly reporting periods) the affected source's excess emissions and continuous monitoring system performance reports continually demonstrate that the source is in compliance with the relevant standard; (B) The Permittee continues to comply with all recordkeeping and monitoring requirements specified in subps. A and UUUUU; and (C) The Administrator does not object to a reduced frequency of reporting for the affected source, as provided in Section 63.10(e)(3)(iii). [40 CFR 63.10(e)(3)(ii), Minn. R. 7019.0100]

5.6.202 The frequency of reporting of excess emissions and continuous monitoring system performance (and summary) reports required to comply with a relevant standard may be reduced only after the Permittee notifies the Administrator in writing of its intention to make such a change and the Administrator does not object to the intended change. In deciding whether to approve a reduced frequency of reporting, the Administrator may review information concerning the source's entire previous performance history during the 5‐year recordkeeping period prior to the intended change, including performance test results, monitoring data, and evaluations of the Permittee's conformance with operation and maintenance requirements. Such information may be used by the Administrator to make a judgment about the source's potential for noncompliance in the future. If the Administrator disapproves the Permittee's request to reduce the frequency of reporting, the Administrator will notify the Permittee in writing within 45 days after receiving notice of the Permittee's intention. The notification from the Administrator to the Permittee will specify the grounds on which the disapproval is based. In the absence of a notice of disapproval within 45 days, approval is automatically granted. [40 CFR 63.10(e)(3)(iii), Minn. R. 7019.0100]

5.6.203 As soon as CMS data indicate that the source is not in compliance with any emission limitation or operating parameter specified in subp. UUUUU, the frequency of reporting shall revert to the frequency specified in subp. UUUUU, and the Permittee shall submit an excess emissions and continuous monitoring system performance (and summary) report for the noncomplying emission points at the next appropriate reporting period following the noncomplying event. After demonstrating ongoing compliance with the


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation relevant standard for another full year, the Permittee may again request approval from the Administrator to reduce the frequency of reporting for subp. UUUUU, as provided for in Section 63.10(e)(3)(ii) and (e)(3)(iii). [40 CFR 63.10(e)(3)(iv), Minn. R. 7019.0100]

5.6.204 Content and submittal dates for excess emissions and monitoring system performance reports. All required excess emissions and monitoring system performance reports and all summary reports shall be delivered or postmarked by the 30th day following the end of each calendar half or quarter, as appropriate. Written reports of excess emissions or exceedances of process or control system parameters shall include all the information required in Section 63.10(c)(5) through (c)(13), in Sections 63.8(c)(7) and 63.8(c)(8), and in subp. UUUUU, and they shall contain the name, title, and signature of the responsible official who is certifying the accuracy of the report. When no excess emissions or exceedances of a parameter have occurred, or a CMS has not been inoperative, out of control, repaired, or adjusted, such information shall be stated in the report. [40 CFR 63.10(e)(3)(v), Minn. R. 7019.0100]

5.6.205 Summary report. As required under Section 63.10(e)(3)(vii) and (e)(3)(viii), one summary report shall be submitted for the hazardous air pollutants monitored at each affected source (unless subp. UUUUU specifies that more than one summary report is required, e.g., one summary report for each hazardous air pollutant monitored). The summary report shall be entitled "Summary Report‐Gaseous and Opacity Excess Emission and Continuous Monitoring System Performance" and shall contain the following information: (A) The company name and address of the affected source; (B) An identification of each hazardous air pollutant monitored at the affected source; (C) The beginning and ending dates of the reporting period; (D) A brief description of the process units; (E) The emission and operating parameter limitations specified in subp. UUUUU; (F) The monitoring equipment manufacturer(s) and model number(s); (G) The date of the latest CMS certification or audit; (H) The total operating time of the affected source during the


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation reporting period; (I) An emission data summary (or similar summary if the Permittee monitors control system parameters), including the total duration of excess emissions during the reporting period (recorded in hours), the total duration of excess emissions expressed as a percent of the total source operating time during that reporting period, and a breakdown of the total duration of excess emissions during the reporting period into those that are due to startup/shutdown, control equipment problems, process problems, other known causes, and other unknown causes; (J) A CMS performance summary (or similar summary if the Permittee monitors control system parameters), including the total CMS downtime during the reporting period (recorded in hours), the total duration of CMS downtime expressed as a percent of the total source operating time during that reporting period, and a breakdown of the total CMS downtime during the reporting period into periods that are due to monitoring equipment malfunctions, nonmonitoring equipment malfunctions, quality assurance/quality control calibrations, other known causes, and other unknown causes; (K) A description of any changes in CMS, processes, or controls since the last reporting period; (L) The name, title, and signature of the responsible official who is certifying the accuracy of the report; and (M) The date of the report. [40 CFR 63.10(e)(3)(vi), Minn. R. 7019.0100]

5.6.206 (vii) If the total duration of excess emissions or process or control system parameter exceedances for the reporting period is less than 1 percent of the total operating time for the reporting period, and CMS downtime for the reporting period is less than 5 percent of the total operating time for the reporting period, only the summary report shall be submitted, and the full excess emissions and continuous monitoring system performance report need not be submitted unless required by the Administrator. (viii) If the total duration of excess emissions or process or control system parameter exceedances for the reporting period is 1 percent or greater of the total operating time for the reporting period, or the total CMS downtime for the reporting period is 5 percent or greater of the total operating time for the reporting period, both the summary report and the excess emissions and continuous monitoring system


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation performance report shall be submitted. [40 CFR 63.10(e)(3)(vii) & (viii), Minn. R. 7019.0100]

5.6.207 Waiver of recordkeeping or reporting requirements. The Permittee shall be subject to and follow the requirements of Section 63.10(f)(1) ‐ (6) if it desires to obtain a waiver from any applicable recordkeeping or reporting requirements. [40 CFR 63.10(f), Minn. R. 7019.0100]

EQUI 3 EU011 Crusher and

Related Transfer Points; EU 011

5.7.1 Opacity < 20 percent opacity. [40 CFR 60.254(a), Minn. R. 7011.1150]

5.7.2 PM < 10 micron <= 3.25 pounds per hour. [Title I Condition: Avoid major modification under 40 CFR 52.21(b)(1) and Minn. R. 7007.3000]

5.7.3 Total Particulate Matter <= 5.37 pounds per hour. [Title I Condition: Avoid major modification under 40 CFR 52.21(b)(1) and Minn. R. 7007.3000]

5.7.4 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 60.7(a)(4), Minn. R. 7019.0100, subp. 1]

5.7.5 TREA18 is a low temperature fabric filter. The Permittee shall vent emissions from EQUI03 (coal crusher) to TREA18 (coal crusher fabric filter) whenever EQUI03 operates, and operate and maintain TREA018 at all times that any emissions are vented to TREA18. The Permittee shall document periods of non‐operation of TREA18. Refer to Subject Item TREA18 for additional applicable requirements for TREA18. [Title I Condition: Avoid major modification under 40 CFR 52.21(b)(1)(i) and Minn. R. 7007.3000]

EQUI 4 EU004 Heating Boiler ‐

34 mmBtu/hr; EU 004

5.8.1 Total Particulate Matter <= 0.6 pounds per million Btu heat input. (The potential to emit based on equipment design and permitted fuel is 0.0143 lb PM/mmBtu). [Minn. R. 7011.0510, subp. 1]

5.8.2 Opacity <= 20 percent opacity except for one six‐minute period per hour of not more than 60 percent opacity. [Minn. R. 7011.0510, subp. 2]

5.8.3 Fuel type limited to distillate fuel oil with a maximum sulfur content of 15 ppmw and propane. [Minn. R. 7007.0800, subp. 2]

5.8.4 The Permittee shall restrict EQUI4 Heat Input <= 29784 million


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation Btu per year 12‐month rolling sum so that EQUI4 qualifies as a Limited Use Boiler as defined at Section 63.7575. [40 CFR 63.7575, Minn. R. 7011.7050]

5.8.5 Heat Input Monitoring and Recordkeeping ‐ By the last day of each month calculate and record: 1. EQUI4 monthly fuel usage and (convert to) monthly heat input for the previous calendar month; 2. EQUI4 heat input for the previous 12‐month period by summing the monthly heat inputs for the previous 12 months. [40 CFR 63.7575, Minn. R. 7007.0800, subps. 4‐5, Minn. R. 7011.7050]

5.8.6 The Permittee owns and operates EQUI4 which is an existing industrial boiler and therefore must comply with pt. 63, subp. DDDDD no later than January 31, 2016. [40 CFR 63.7495(b), Minn. R. 7011.7050]

5.8.7 The Permittee must meet the notification requirements in Section 63.7545 according to the schedule in Section 63.7545 and in pt. 63, subp. A. Some of the notifications must be submitted before the Permittee is required to comply with the emission limits and work practice standards in pt. 63, subp. DDDDD. [40 CFR 63.7495(d), Minn. R. 7011.7050]

5.8.8 EQUI4 is a Limited Use boiler. [40 CFR 63.7499(o), Minn. R. 7011.7050]

5.8.9 The Permittee must meet the tune‐up work practice standard in Table 3 of subp. DDDDD. [40 CFR 63.7500(a)(1), Minn. R. 7011.7050]

5.8.10 At all times, the Permittee must operate and maintain EQUI4 in a manner consistent with safety and good air pollution control practices for minimizing emissions. Determination of whether such operation and maintenance procedures are being used will be based on information available to the Administrator that may include, but is not limited to, monitoring results, review of operation and maintenance procedures, review of operation and maintenance records, and inspection of the source. [40 CFR 63.7500(a)(3), Minn. R. 7011.7050]

5.8.11 The Permittee shall complete a tune‐up of EQUI4 every 5 years as specified in Section 63.7540. EQUI4 is not subject to the emission limits in Tables 1 and 2 or 11 through 13 to 40 CFR pt. 63, subp. DDDDD, the annual tune‐up, or the energy assessment requirements in Table 3 to subp. DDDDD, or the operating limits in Table 4 to subp. DDDDD. [40 CFR 63.7500(c), Minn. R. 7011.7050]

5.8.12 The Permittee must be in compliance with the 5‐year tune‐up work practice standard in subp. DDDDD. [40 CFR 63.7505(a), Minn. R. 7011.7050]

5.8.13 (e) The Permittee must complete an initial tune‐up of EQUI4 by following the procedures described in Section


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 63.7540(a)(10)(i) through (vi) no later than January 13, 2016 except as specified in Section 63.7510(j). (j) If EQUI4 has not operated between the January 31, 2013 effective date of pt. 63, subp. DDDDD and the January 31, 2016 compliance date specified in Section 63.7495, the Permittee must complete an initial tune‐up by following the procedures described in Section 63.7540(a)(10)(i) through (vi) no later than 30 days after the re‐start of EQUI4. [40 CFR 63.7510(e) & (j), Minn. R. 7011.7050]

5.8.14 The Permittee must conduct the 5‐year performance tune‐up according to Section 63.7540(a)(12). Each 5‐year tune‐up specified in Section 63.7540(a)(12) must be conducted no more than 61 months after the previous tune‐up. [40 CFR 63.7515(d), Minn. R. 7011.7050]

5.8.15 The Permittee must demonstrate continuous compliance with the boiler tune‐up work practice standard in Table 3 to pt. 63, subp. DDDDD. [40 CFR 63.7540(a), Minn. R. 7011.7050]

5.8.16 EQUI4 meets the definition of a limited‐use boiler in Section 63.7575, and therefore, the Permittee must conduct a tune‐up of EQUI4 every 5 years as specified in Section 63.7540(a)(10)(i) through (vi) to demonstrate continuous compliance. The Permittee may delay the burner inspection specified in section 63.7540(a)(10)(i) until the next scheduled or unscheduled unit shutdown, but the Permittee must inspect each burner at least once every 72 months. [40 CFR 63.7540(a)(12), Minn. R. 7011.7050]

5.8.17 The Permittee must conduct a tune‐up on EQUI4 every 5 years to demonstrate continuous compliance according to the requirements of Section 63.7540(a)(10)(i) through (vi). The Permittee must conduct the tune‐up while burning the type of fuel (or fuels in case of units that routinely burn a mixture) that provided the majority of the EQUI4 heat input over the 12 months prior to the tune‐up. The annual tune‐up frequency does not apply to EQUI4 because it is a limited‐use boiler as defined in Section 63.7575. (i) As applicable, inspect the burner, and clean or replace any components of the burner as necessary (you may perform the burner inspection any time prior to the tune‐up or delay the burner inspection until the next scheduled unit shutdown). Units that produce electricity for sale may delay the burner inspection until the first outage, not to exceed 36 months from the previous inspection. At units where entry into a piece of process equipment or into a storage vessel is required to complete the tune‐up inspections, inspections are required only during planned entries into the storage vessel or process equipment;


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation (ii) Inspect the flame pattern, as applicable, and adjust the burner as necessary to optimize the flame pattern. The adjustment should be consistent with the manufacturer's specifications, if available; (iii) Inspect the system controlling the air‐to‐fuel ratio, as applicable, and ensure that it is correctly calibrated and functioning properly (you may delay the inspection until the next scheduled unit shutdown). Units that produce electricity for sale may delay the inspection until the first outage, not to exceed 36 months from the previous inspection; (iv) Optimize total emissions of CO. This optimization should be consistent with the manufacturer's specifications, if available, and with any NOX requirement to which the unit is subject; (v) Measure the concentrations in the effluent stream of CO in parts per million, by volume, and oxygen in volume percent, before and after the adjustments are made (measurements may be either on a dry or wet basis, as long as it is the same basis before and after the adjustments are made). Measurements may be taken using a portable CO analyzer; and (vi) Maintain on‐site and submit, if requested by the Administrator, a report containing the information in paragraphs (a)(10)(vi)(A) through (C) of this section, (A) The concentrations of CO in the effluent stream in parts per million by volume, and oxygen in volume percent, measured at high fire or typical operating load, before and after the tune‐up of the boiler or process heater; (B) A description of any corrective actions taken as a part of the tune‐up; and (C) The type and amount of fuel used over the 12 months prior to the tune‐up, but only if the unit was physically and legally capable of using more than one type of fuel during that period. Units sharing a fuel meter may estimate the fuel used by each unit. [40 CFR 63.7540(a)(10), Minn. R. 7011.7050]

5.8.18 The Permittee must report each instance in which it did not meet the five‐year tune‐up operating limit in Table 3 to pt. 63, subp. DDDDD. These instances are deviations from the operating limit in subp. DDDDD. These deviations must be reported according to the requirements in Section 63.7550. [40 CFR 63.7540(b), Minn. R. 7011.7050]

5.8.19 Notifications. The Permittee must submit to the Administrator:


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation (a) all applicable notifications in Sections 63.7(b) and (c), 63.8(e), (f)(4) and (6), and 63.9(b) through (h) by the dates specified; and, (b) an Initial Notification not later than 120 days after January 31, 2013 as specified in Section 63.9(b)(2). [40 CFR 63.7545(a)&(b), Minn. R. 7011.7050]

5.8.20 The Permittee must submit each applicable report in Table 9 of pt. 63, subp. DDDDD. [40 CFR 63.7550(a), Minn. R. 7011.7050]

5.8.21 The Permittee may submit only a 5‐year compliance report, as specified in Section 63.7550(b)(1) through (4), instead of a semi‐annual compliance report. (1) The first compliance report must cover the period beginning on the January 31, 2016 compliance date and ending (5 years after the compliance date) on January 31, 2021. (2) The first 5‐year compliance report must be postmarked or submitted no later than January 31. (3) Each subsequent 5‐year compliance report must cover the 5‐year periods from January 1 to December 31. (4) Each subsequent 5‐year compliance report must be postmarked or submitted no later than January 31. [40 CFR 63.7550(b), Minn. R. 7011.7050]

5.8.22 A compliance report must contain the following information (based on how the facility chooses to comply with the limits set in pt. 63, subp. DDDDD). (1) The Permittee must submit a compliance report with the information in Section 63.7550(c)(5)(i) through (iv) and (xiv). (5)(i) Permittee and Facility name and address. (ii) Process unit (EQUI4) information, emissions limitations, and operating parameter limitations. (iii) Date of report and beginning and ending dates of the reporting period. (iv) The total operating time during the reporting period. (xiv) Date of the most recent EQUI4 tune‐up. Include the date of the most recent burner inspection if it was not done on a 5‐year period and was delayed until the next scheduled or unscheduled unit shutdown. [40 CFR 63.7550(c), Minn. R. 7011.7050]

5.8.23 The Permittee must submit all reports required by Table 9 of pt. 63, subp. DDDDD electronically using CEDRI that is accessed through the EPA's Central Data Exchange (CDX) (www.epa.gov/cdx). However, if the reporting form specific to


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation subp. DDDDD is not available in CEDRI at the time that the report is due the report the Permittee must submit the report to the Administrator at the appropriate address listed in Section 63.13. At the discretion of the Administrator, the Permittee must also submit these reports, to the Administrator in the format specified by the Administrator. [40 CFR 63.7550(h)(3), Minn. R. 7011.7050]

5.8.24 Recordkeeping. The Permittee must keep the following records: (a)(1) A copy of each notification and report submitted to comply with pt. 63, subp. DDDDD, including all documentation supporting any Initial Notification or Notification of Compliance Status or semiannual compliance report that you submitted, according to the requirements in Section 63.10(b)(2)(xiv). (a)(2) Records of performance tests, fuel analyses, or other compliance demonstrations and performance evaluations as required in Section 63.10(b)(2)(viii). (a)(3) A copy of the federally enforceable permit that limits the annual capacity factor to less than or equal to 10 percent and fuel use records for the days the boiler or process heater was operating. [40 CFR 63.7555, Minn. R. 7011.7050]

5.8.25 (a) Records must be in a form suitable and readily available for expeditious review, according to Section 63.10(b)(1). (b) As specified in Section 63.10(b)(1), the Permittee must keep each record for 5 years following the date of each occurrence, measurement, maintenance, corrective action, report, or record. (c) The Permittee must keep each record on site, or they must be accessible from on site (for example, through a computer network), for at least 2 years after the date of each occurrence, measurement, maintenance, corrective action, report, or record, according to Section 63.10(b)(1). Records can be kept off site for the remaining 3 years. [40 CFR 63.7560, Minn. R. 7011.7050]

5.8.26 General Provisions. Table 10 to pt. 63, subp. DDDDD shows which parts of the General Provisions in Sections 63.1 through 63.15 apply to the Permittee. [40 CFR 63.7565, Minn. R. 7011.7050]

EQUI 5 EU002 Boiler No. 2; EU

002

5.9.1 Total Particulate Matter <= 0.6 pounds per million Btu heat input 3‐hour average (excluding condensable particulate


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation matter). An additional limit of 0.030 pound per million Btu (from a 2014 Consent Decree) located in COMG2 also applies, and a 0.03 pounds per million Btu (from pt. 63, subp. UUUUU) located in COMG7 may apply depending on the PM/HAPs selected compliance option under pt. 63, subp. UUUUU. [Minn. R. 7011.0510, subp. 1]

5.9.2 Sulfur Dioxide <= 4.0 pounds per million Btu heat input 3‐hour average. A 0.300 pound per million Btu (from the 2014 Consent Decree) limit located in COMG2 also applies, and a 0.20 pound per million Btu (from pt. 63, subp. UUUUU) limit located in COMG7 may also apply depending upon the Hydrogen Chloride compliance option selected in COMG7. [Minn. R. 7011.0510, subp. 1]


5.9.4 Sulfur Dioxide <= 242.2 pounds per hour 30‐day rolling average excluding startup and shutdown. This limit is based on the 330.48 pound per hour (one‐hour average basis) 'critical emission value' to avoid exceedance of the 1‐hour National Ambient Air Quality Standard for SO2. [40 CFR 50.17, Minn. R. 7009.0020, Minn. R. 7009.0080]

5.9.5 Startup and Shutdown Events Recordkeeping: The Permittee shall generate and keep a record of each startup and each shutdown event. The record shall include the date, and the time (to the nearest hour) of the commencement and completion of each event. This data shall be collected for a period of five years after permit issuance, or until the next reissuance of this operating permit, which ever is longer. This data shall be submitted with the next application for reissuance of this operating permit. 'Startup' and 'Shutdown' are defined at 40 CFR Section 63.10042. [40 CFR 50.17, Minn. R. 7007.0800, subp. 2, Minn. R. 7007.0800, subp. 4(B)]

5.9.6 The Permittee shall track the number of hourly exceedances of the 330.48 pound per hour (one‐hour average basis) 'critical emission value'. The Permittee must retain this information for at least five years from the date of permit issuance or until the MPCA re‐issues the facility's Part 70 operating permit, whichever is longer. The Permittee must also submit this information with its application for a Part 70 permit reissuance. [40 CFR 50.17, Minn. R. 7007.0800, subp. 2, Minn. R. 7007.0800, subp. 4(B)]

5.9.7 Particulate Matter < 10 micron (PM < 10) and Front‐half Particulate Matter (PM) Emission Limits and Compliance Options: The Permittee shall follow Option 1 or Option 2 described


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 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: 40 CFR 52.21(r)(6), Title I Condition: Avoid major modification under 40 CFR 52.21(b)(2) and Minn. R. 7007.3000]

5.9.8 PM < 10 Compliance Options: OPTION 1 1a. Periodically stack test to validate EQUI5 PM10 emissions are less than or equal to the EQUI5 0.120 lb/mmBtu PM10 emission factor, and 1b. Monitor, record, and report EQUI5 PM10 emissions as required by 40 CFR Section 52.21(r)(6); OR OPTION 2 2. Meet the EQUI5 327 ton per year (12‐month rolling sum basis) PM10 limit and all associated monitoring, recordkeeping, and reporting requirements in this permit. If the most recent EQUI5 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: 40 CFR 52.21(r)(6), Title I Condition: Avoid major modification under 40 CFR 52.21(b)(2) and Minn. R. 7007.3000]

5.9.9 PM < 10 micron <= 0.120 pounds per million Btu (this is an emission factor and not a limit). The Permittee shall validate this factor through required periodic performance testing. If performance testing shows a factor greater than 0.120 lb/mmBtu, the Permittee shall meet the 327 tpy limit and related requirements for Option 2. [Title I Condition: 40 CFR 52.21(r)(6), Title I Condition: Avoid major modification under 40 CFR 52.21(b)(2) and Minn. R. 7007.3000]

5.9.10 PM < 10 micron <= 327 tons per year 12‐month rolling sum. This limit applies commencing on the first day of the month that the Permittee becomes subject to Option 2. The Permittee becomes subject to Option 2 upon receipt of the Notice of Verification letter stating that the most recent PM10 performance test measured the PM10 emission factor in excess of 0.120 lb/mmBtu. Upon becoming subject to this 327 ton per year limit, the Permittee shall calculate and record the monthly PM10 emissions for the prior 11 months using the most recent PM10


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation performance test‐measured emission factor. [Title I Condition: 40 CFR 52.21(r)(6), Title I Condition: Avoid major modification under 40 CFR 52.21(b)(2) and Minn. R. 7007.3000]

5.9.11 Front‐half Particulate Matter Compliance Options: Option 1 1.a. Stack test to validate EQUI5 PM emissions are less than or equal to the EQUI5 0.039 lb/mmBtu PM emission factor, and 1.b. Monitor, record, and report EQUI5 PM emissions as required by 40 CFR Section 52.21(r)(6); OR Option 2 2. Meet the EQUI5 106 ton per year (12‐month rolling sum basis) PM limit and all associated monitoring, recordkeeping, and reporting requirements in this permit. Front‐half PM: If the most recent EQUI5 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: 40 CFR 52.21(r)(6), Title I Condition: Avoid major modification under 40 CFR 52.21(b)(2) and Minn. R. 7007.3000]

5.9.12 Front‐half Particulate Matter <= 0.039 pounds per million Btu 12‐month rolling sum (this is an emission factor and not a limit). The Permittee shall validate this factor through required periodic performance testing. If performance testing shows a factor greater than 0.039 lb/mmBtu, the Permittee shall meet the 106 tpy limit and related requirements for option 2. [Title I Condition: 40 CFR 52.21(r)(6), Title I Condition: Avoid major modification under 40 CFR 52.21(b)(2) and Minn. R. 7007.3000]

5.9.13 Front‐half Particulate Matter <= 106 tons per year 12‐month rolling sum. This limit applies commencing on the first day of the month that the Permittee becomes subject to Option 2. The Permittee becomes subject to Option 2 upon receipt of the Notice of Verification letter stating that the most recent PM performance test measured the PM emission factor in excess of 0.039 lb/mmBtu. Upon becoming subject to this 106 ton per year limit, the Permittee shall calculate and record the monthly PM emissions for the prior 11 months using the most recent PM performance test‐measured emission factor. [Title I Condition: 40 CFR 52.21(r)(6), Title I Condition: Avoid major modification under 40 CFR 52.21(b)(2) and Minn. R. 7007.3000]

5.9.14 EQUI5 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


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation calculate and record EQUI5 monthly fuel usage of sub‐bituminous coal and bituminous coal. [Minn. R. 7007.0800, subps. 4‐5, Title I Condition: Avoid major modification under 40 CFR 52.21(b)(2) and Minn. R. 7007.3000]

5.9.15 EQUI5 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 EQUI5 monthly PM10 emissions as follows: EQUI5 PM10 = (FC * HC * EF)/2000 where: EQUI5 PM10 = monthly EQUI5 PM10 emissions for each coal type (tons) FC = EQUI5 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 EQUI5 PM10 emission factor for each coal type (lb/mmBtu) 2. Calculate and record the total EQUI5 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]

5.9.16 EQUI5 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 EQUI5 monthly PM emissions as follows: EQUI5 PM = (FC * HC * EF)/2000 where: EQUI5 PM = monthly EQUI5 PM emissions for each coal type (tons) FC = EQUI5 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 EQUI5 PM emission factor for each coal type (lb/mmBtu)


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 2. Calculate and record the total EQUI5 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]

5.9.17 EQUI5 PM10 Periodic Monitoring: The EQUI5 PM CAM plan requirements (use of PM CEMS) shall fulfill periodic monitoring for PM10 emissions, unless agency‐approved EQUI5 PM and PM10 performance testing demonstrates the test‐measured PM10 emission factor is a higher percentage of the 0.120 lb/mmBtu emission factor than PM is of the 0.039 lb/mmBtu PM emission factor. If the above described circumstance occurs, the Permittee shall submit an application for a major permit amendment to revise the EQUI5 PM10 periodic monitoring requirements in this permit, no later than 120 days after receipt of the written notice from the agency of test results demonstrating the above PM/PM10 relationship.. [Minn. R. 7007.0800, subp. 4(B), Minn. R. 7007.0800, subp. 5(A)]

5.9.18 Permitted Fuels: bituminous coal, subbituminous coal, distillate fuel oil, used oil, and propane. Distillate fuel oil may be combusted providing EQUI5 obtains more than 10% of its average annual heat input from coal during any 3 consecutive calendar years, and obtains more than 15% of its heat input from coal during any one calendar year, in order to meet the definition of a coal‐fired electric utility steam generating unit at 40 CFR Section 63.10042. Propane is only permitted for use in a propane‐fired 'SHOCKSystem' that cleans boiler firebox surfaces of slag and ash in EQUI5. The Permittee may also burn nonhazardous secondary materials that are not solid wastes when such materials are evaluated and authorized according to the requirements of 40 CFR pt. 241. The Permittee is also allowed to burn alternative fuels during test burns providing the alternative fuels are traditional fuels or nonhazardous secondary materials that are not solid wastes according to the requirements of 40 CFR pt. 241, and the test burns are conducted according to the COMG2 requirements of this permit. [Minn. R. 7007.0800, subp. 2]

5.9.19 Boiler Cleaning Agents: The Permittee shall not incinerate boiler cleaning agents in any of the facility boilers unless such agents are determined according to the requirements of 40 CFR pt. 241, subp. B, to be a nonhazardous secondary material that is not solid waste when combusted. [40 CFR pt. 241,


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation Minn. R. 7007.0800, subp. 2]

5.9.20 The Permittee shall operate and maintain each EQUI5 treatment (control) device listed in Section 4 'Summary of Subject Items' of this permit and also shown below, whenever EQUI5 operates except as specified below. TREA2 ESP TREA5 SNCR Urea Injection & ROFA TREA6 Hydrated Lime Injection TREA16 Ammonia Injection (not required*) TREA17 SO3 Injection (not required*) TREA21 Activated Carbon Injection TREA27 Sodium Bicarbonate Injection *The Consent Decree only requires operation of Electrostatic Precipitator TREA2 for particulate matter control and the Permittee has demonstrated these controls are not necessary for meeting applicable PM limits. [Minn. R. 7007.0800, subp. 2&14]

5.9.21 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. 3(B), Minn. R. 7017.2025, subp. 2(A)]

5.9.22 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


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 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)]

5.9.23 Short Term Emergency and Testing (STET) Operating hours limit: EQUI5 may operate up to 40 hours per year to demonstrate the Uniform Rating of Generating Equipment capacity and to meet emergency energy supply needs. EQUI5 must meet emission limits during STET operation. The Permittee shall keep a record of all STET operation including the clock start and stop times of STET operation, and the actual heat input rate during each STET operating event. [Minn. R. 7007.0800, subp. 2]

5.9.24 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]

5.9.25 Compliance Assurance Monitoring: The Permittee shall use the PM, SO2, and NOx Continuous Emissions Monitoring Systems, associated diluent monitor(s), and Data Acquisition and Handling System (EQUI90) for meeting the requirements of 40 CFR pt. 64 for EQUI5 for these pollutants. Unit 2 (EQUI5) CEMS (excluding any diluent monitors) are as follows: PM: EQUI96 (MR 049) SO2: EQUI30 (MR 034) NOx: EQUI93 (MR 046) The Permittee shall design these monitoring systems to allow for reporting of exceedances, consistent with any period for reporting of exceedances in an underlying requirement. Refer to COMG6 for CEMS installation, operation, maintenance, and


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation quality assurance/quality control requirements. [40 CFR 64.3(d), Minn. R. 7017.0200]

EQUI 63 EU005 Emergency

Diesel Generator (1600 hp; 1957); EU 005

5.10.1 Opacity <= 20 percent opacity once operating temperatures have been attained. [Minn. R. 7011.2300, subp. 1]

5.10.2 Sulfur Dioxide <= 0.5 pounds per million Btu heat input. (The potential to emit based on equipment design and permitted fuel is 0.000015 lb SO2/mmBtu). [Minn. R. 7011.2300, subp. 2]

5.10.3 Permitted fuel: Restricted to diesel fuel meeting the requirements of 40 CFR Section 80.510(c). [Minn. R. 7005.0100, subp. 35a]

5.10.4 The Permittee is subject to 40 CFR pt. 63, subp. ZZZZ because it owns and operates EQUI63 (a stationary reciprocating internal combustion engine (RICE)) located at a major HAP source and EQUI63 is not operated for the purpose of testing at a stationary RICE test cell/stand. [40 CFR 63.6585, Minn. R. 7011.8150]

5.10.5 EQUI63 is an existing stationary RICE with a site rating greater than 500 hp constructed before December 19, 2002, and located at a major HAP source. [40 CFR 63.6590(a)(1)(i), Minn. R. 7011.8150]

5.10.6 EQUI63 is an Existing Emergency Stationary RICE that is not subject to the requirements of 40 CFR pt. 63, subps. A and ZZZZ, including initial notification requirements because EQUI63 does not operate or is not contractually obligated to be available for more than 15 hours per calendar year for the purposes specified in Section 63.6640(f)(2)(ii) and (iii). [40 CFR 63.6590(b)(3)(iii), 40 CFR 63.6675, Minn. R. 7011.8150]

5.10.7 Hours of Operation: The Permittee shall maintain documentation on site that EQUI63 is an emergency generator by design that qualifies under the U.S. EPA memorandum entitled "Calculating Potential to Emit (PTE) for Emergency Generators" dated September 6, 1995, limiting operation to 500 hours per year. [Minn. R. 7007.0800, subp. 4&5]


001

5.11.1 Total Particulate Matter <= 0.6 pounds per million Btu heat input 3‐hour average (excluding condensable particulate matter). An additional limit of 0.030 pound per million Btu (from a 2014 Consent Decree) located in COMG2 also applies, and a 0.03 pounds per million Btu (from pt. 63, subp. UUUUU) located in COMG7 may apply depending on the PM/HAPs selected compliance option under pt. 63, subp. UUUUU. [Minn. R. 7011.0510, subp. 1]


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 5.11.2 Sulfur Dioxide <= 4.0 pounds per million Btu heat input 3‐hour

average. A 0.300 pound per million Btu (from the 2014 Consent Decree) limit located in COMG2 also applies, and a 0.20 pound per million Btu (from pt. 63, subp. UUUUU) limit located in COMG7, may also apply depending upon the Hydrogen Chloride compliance option selected in COMG7. [Minn. R. 7011.0510, subp. 1]


5.11.4 Sulfur Dioxide <= 258.0 pounds per hour 30‐day rolling average excluding startup and shutdown. This limit is based on the 330.48 pound per hour (one‐hour average basis) 'critical emission value' to avoid exceedance of the 1‐hour National Ambient Air Quality Standard for SO2. [40 CFR 50.17, Minn. R. 7009.0020, Minn. R. 7009.0080]

5.11.5 Startup and Shutdown Events Recordkeeping: The Permittee shall generate and keep a record of each startup and each shutdown event. The record shall include the date, and the time (to the nearest hour) of the commencement and completion of each event. This data shall be collected for a period of five years after permit issuance, or until the next reissuance of this operating permit, which ever is longer. This data shall be submitted with the next application for reissuance of this operating permit. 'Startup' and 'Shutdown' are defined at 40 CFR Section 63.10042. [40 CFR 50.17, Minn. R. 7007.0800, subp. 2, Minn. R. 7007.0800, subp. 4(B)]

5.11.6 The Permittee shall track the number of hourly exceedances of the 330.48 pound per hour (one‐hour average basis) 'critical emission value' for EQUI64 SO2 emissions and EQUI5 SO2 emissions. The Permittee must retain this information for at least five years from the date of permit issuance or until the MPCA re‐issues the facility's Part 70 operating permit, whichever is longer. The Permittee must also submit this information with its application for a Part 70 permit reissuance. [40 CFR 50.17, Minn. R. 7007.0800, subp. 2, Minn. R. 7007.0800, subp. 4(B)]

5.11.7 The Permittee shall operate and maintain each EQUI64 treatment (control) device listed in Section 4 'Summary of Subject Items' of this permit and also shown below, whenever EQUI64 operates except as specified below. TREA1 ESP TREA22 SNCR Urea Injection & ROFA TREA23 Hydrated Lime Injection TREA24 Activated Carbon Injection TREA25 SO3 Injection (not required*)


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation TREA26 Ammonia Injection (not required*) TREA28 Sodium Bicarbonate Injection *The Consent Decree only requires operation of Electrostatic Precipitator TREA1 for particulate matter control and the Permittee has demonstrated these controls are not necessary for meeting applicable PM limits. [Minn. R. 7007.0800, subp. 2&14]

5.11.8 Permitted Fuels: bituminous coal, subbituminous coal, distillate fuel oil, used oil, and propane. Distillate fuel oil may be combusted providing EQUI64 obtains more than 10% of its average annual heat input from coal during any 3 consecutive calendar years, and obtains more than 15% of its heat input from coal during any one calendar year, in order to meet the definition of a coal‐fired electric utility steam generating unit at 40 CFR Section 63.10042. Propane is only permitted for use in a propane‐fired 'SHOCKSystem' that cleans boiler firebox surfaces of slag and ash in EQUI64. The Permittee may also burn nonhazardous secondary materials that are not solid wastes when such materials are evaluated and authorized according to the requirements of 40 CFR pt. 241. The Permittee is also allowed to burn alternative fuels during test burns providing the alternative fuels are traditional fuels or nonhazardous secondary materials that are not solid wastes according to the requirements of 40 CFR pt. 241, and the test burns are conducted according to the COMG2 requirements of this permit. [Minn. R. 7007.0800, subp. 2]

5.11.9 Boiler Cleaning Agents: The Permittee shall not incinerate boiler cleaning agents in any of the facility boilers unless such agents are determined according to the requirements of 40 CFR pt. 241, subp. B, to be a nonhazardous secondary material that is not solid waste when combusted. [40 CFR pt. 241, Minn. R. 7007.0800, subp. 2]

5.11.10 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.


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 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), Minn. R. 7017.2025, subp. 2(A)]

5.11.11 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)]

5.11.12 Short Term Emergency and Testing (STET) Operating hours limit: EQUI64 may operate up to 40 hours per year to demonstrate the Uniform Rating of Generating Equipment capacity and to meet emergency energy supply needs. EQUI64 must meet emission limits during STET operation. The Permittee shall keep a record of all STET operation including the clock start and stop times of STET operation, and the actual heat input rate during each STET operating event. [Minn. R. 7007.0800, subp. 2]

5.11.13 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.


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation In no case will STET operation be higher than allowed by an existing permit condition. [Minn. R. 7007.0800, subp. 2]

5.11.14 Compliance Assurance Monitoring: The Permittee shall use the PM, SO2, and NOx Continuous Emissions Monitoring Systems, associated diluent monitor(s), and Data Acquisition and Handling System (EQUI90) for meeting the requirements of 40 CFR pt. 64 for these pollutants. Unit 1 (EQUI64) CEMS (excluding any diluent monitors) are as follows: PM: EQUI95 (MR 048) SO2: EQUI43 (MR 029) NOx: EQUI91 (MR 044) The Permittee shall design these monitoring systems to allow for reporting of exceedances, consistent with any period for reporting of exceedances in an underlying requirement. Refer to COMG6 for CEMS installation, operation, maintenance, and quality assurance/quality control requirements. [40 CFR 64.3(d), Minn. R. 7017.0200]

EQUI 65 EU003 Boiler No. 3 5.12.1 The Permittee shall not operate EQUI65 (Boiler No. 3). [Minn.

R. 7007.0800, subp. 2] EQUI 88 EU006 Fly Ash Silo; EU

006

5.13.1 Total Particulate Matter <= 0.30 grains per 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)]

5.13.2 Opacity <= 20 percent opacity. [Minn. R. 7011.0715, subp. 1(B)]

5.13.3 TREA10 is a low temperature fabric filter. The Permittee shall vent emissions from EQUI88 (fly ash silo) to TREA10 (fly ash silo fabric filter) whenever EQUI88 operates, and operate and maintain TREA10 at all times that any emissions are vented to TREA10. The Permittee shall document periods of non‐operation of TREA10. Refer to Subject Item TREA10 for additional requirements applicable to TREA10. [Minn. R. 7007.0800, subp. 2&14]

EQUI 89 EU007 Coal Tripper

Floor; EU 007

5.14.1 Total Particulate Matter <= 3.70 pounds per hour. [Title I


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation Condition: Avoid major modification under 40 CFR 52.21(b)(2)(i)]



5.14.4 TREA04 is a low temperature fabric filter that is listed control equipment under Minn. R. 7011.0060 to 7011.0080. The Permittee shall vent emissions from EQUI89 to TREA04 whenever EQUI89 is operating, and operate and maintain TREA04 at all times that any emissions are vented to TREA04. The Permittee shall document periods of TREA04 non‐operation. Refer to Subject Item TREA4 for additional requirements applicable to TREA4. [Minn. R. 7011.0075, subp. 1]

EQUI 99 EU012 Bottom Ash Silo;

EU 012



5.15.3 TREA29 is a low temperature fabric filter that is listed control equipment under Minn. R. 7011.0060 to 7011.0080. The Permittee shall vent emissions from EQUI99 to TREA29 whenever EQUI99 operates, and operate and maintain TREA29 at all times that any emissions are vented to TREA29. The Permittee shall document periods of non‐operation of TREA29. Refer to Subject Item TREA29 for additional requirements applicable to TREA29. [Minn. R. 7011.0075, subp. 1]

EQUI 100 EU013 Ash Loadout; EU

013

5.16.1 PM < 2.5 micron <= 2.05 pounds per hour. [Title I Condition: Avoid major modification under 40 CFR 52.21(b)(2)(i)]

5.16.2 Total Particulate Matter <= 5.13 pounds per hour. [Title I Condition: Avoid major modification under 40 CFR 52.21(b)(i)]

5.16.3 Total Particulate Matter <= 0.30 grains per 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.


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation Because this industrial process equipment is controlled by control equipment which has a collection efficiency of 99 percent by weight, this industrial process equipment is considered to be in compliance with this requirement. [Minn. R. 7011.0710, subps. 1(A)and 2]


5.16.5 TREA30 is a low temperature fabric filter that is listed control equipment under Minn. R. 7011.0060 to 7011.0080. The Permittee shall vent emissions from EQUI100 to TREA30 whenever EQUI100 operates, and operate and maintain TREA30 at all times that any emissions are vented to TREA30. The Permittee shall document periods of non‐operation of TREA30. Refer to Subject Item TREA30 for additional applicable requirements for TREA30. [Minn. R. 7011.0075, Title I Condition: Avoid major modification under 40 CFR 52.21(b)(1)(i) and Minn. R. 7007.3000]

EQUI 101 EU014 Diesel fire pump

‐ 1955; EU 014

5.17.1 Opacity <= 20 percent opacity once operating temperatures have been attained. [Minn. R. 7011.2300, subp. 1]

5.17.2 Sulfur Dioxide <= 0.50 pounds per million Btu heat input. (The potential to emit based on equipment design and permitted fuel is 0.000015 lb SO2/mmBtu). [Minn. R. 7011.2300, subp. 2]

5.17.3 Permitted fuel: Restricted to diesel fuel meeting the requirements of 40 CFR Section 80.510(c). [Minn. R. 7005.0100, subp. 35a]

5.17.4 Hours of Operation: The Permittee shall maintain documentation on site that EQUI101 is an emergency generator by design that qualifies under the U.S. EPA memorandum entitled "Calculating Potential to Emit (PTE) for Emergency Generators" dated September 6, 1995, limiting operation to 500 hours per year. [Minn. R. 7007.0800, subp. 4&5]

5.17.5 Circumvention. The Permittee shall not build, erect, install, or use any article, machine, equipment, or process to conceal an emission that would otherwise constitute noncompliance with a relevant standard. Such concealment includes, but is not limited to: (1) The use of diluents to achieve compliance with a relevant standard based on the concentration of a pollutant in the effluent discharged to the atmosphere; or (2) The use of gaseous diluents to achieve compliance with a


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation relevant standard for visible emissions. [40 CFR 63.4(b), Minn. R. 7011.7000]

5.17.6 After the effective date of any relevant standard promulgated by the Administrator under 40 CFR pt. 63, equipment added (or a process change) to an affected source that is within the scope of the definition of affected source under the relevant standard must be considered part of the affected source and subject to all provisions of the relevant standard established for that affected source. [40 CFR 63.5(b), Minn. R. 7011.7000]

5.17.7 Prior to construction or reconstruction of a major‐emitting "affected source" under the promulgated MACT standards, the Permittee must apply for and obtain an air emission permit. [40 CFR 63.5(b)(3)& Minn. R. 7011.7000]

5.17.8 After the effective date of any relevant standard promulgated by the Administrator under 40 CFR pt. 63, the Permittee who constructs a new affected source that is not major‐emitting or reconstructs an affected source that is not major‐emitting that is subject to such standard, or reconstructs a source such that the source becomes an affected source subject to the standard, must notify the Administrator of the intended construction or reconstruction. The notification must be submitted in accordance with the procedures in 40 CFR Section 63.9(b). [40 CFR 63.5(b)(4)& Minn. R. 7011.7000]

5.17.9 Recordkeeping: The Permittee shall maintain files of all information required by 40 CFR pt. 63 in a form suitable and readily available for expeditious inspection and review. The files should be retained for at least 5 years following the date of each occurrence, measurement, maintenance, corrective action, report, or record. Only the most recent two years of information must be kept on site. [40 CFR 63.10(b)(1), Minn. R. 7019.0100, subp. 2(B)]

5.17.10 The Permittee shall maintain relevant records for EQUI101 of vi) each period during which a continuous monitoring system (CMS) is malfunctioning or inoperative; vii) all required measurements needed to demonstrate compliance with a relevant standard; viii) all results of performance test, CMS performance evaluations, and opacity and visible emission observations; ix) all measurements as may be necessary to determine the conditions of performance tests and performance evaluations; x) all CMS calibration checks; xi) all adjustments and maintenance performed on CMS; xii) any information demonstrating whether a source is meeting the requirements for a waiver of record keeping or reporting requirements under pt. 63; and xii) all emission levels relative to the criterion for obtaining permission to use an alternative to the relative accuracy test, if


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation the source has been granted such permission under Section 63.8(f)(6); and xiv) all documents supporting initial notifications and notifications of compliance status. [40 CFR 63.10(b)(2)(vi) ‐ (xiv), Minn. R. 7019.0100, subp. 2(B)]

5.17.11 The Permittee is subject to 40 CFR pt. 63, subp. ZZZZ because it owns and operates EQUI101 (a stationary reciprocating internal combustion engine (RICE)) located at a major HAP source and EQUI101 operation does not involve testing at a stationary RICE test cell/stand. [40 CFR 63.6585, Minn. R. 7011.8150]

5.17.12 EQUI101 is located at a major HAP source and is an existing stationary RICE with a site rating equal to or less than 500 hp that was constructed before June 12, 2006. [40 CFR 63.6590(a)(1)(ii), Minn. R. 7011.8150]

5.17.13 EQUI101 is a fire pump used to pump water for fire fighting. EQUI101 meets the definition of Emergency Stationary RICE at 40 CFR Section 63.6675 because it meets all of the criteria in paragraphs (1) through (3) of the definition at Section 63.6675. However, because EQUI101 is a fire pump Emergency Stationary RICE and does not generate electricity, and is not permitted to generate electricity, operation of EQUI101 could not violate paragraph (3) of the Emergency Stationary RICE definition at Section 63.6675. (Paragraph (3) refers to emergency stationary RICE operation requirements for generating electricity under Section 63.6640(f)(2)(ii) and (iii) as part of a financial arrangement with another entity for either emergency demand response or for periods when there is a deviation of voltage or frequency of 5 percent or greater below standard voltage or frequency). If EQUI101 does not comply with the requirements specified in Section 63.6640(f), then EQUI101 is not an emergency stationary RICE under subp. ZZZZ. [40 CFR 63.6675, Minn. R. 7007.0800, subp. 2, Minn. R. 7011.8150]

5.17.14 The Permittee must comply with the following requirements in 40 CFR pt. 63, subp. ZZZZ, Table 2c. a. Change oil and filter every 500 hours of operation or annually, whichever comes first. b. Inspect air cleaner every 1,000 hours of operation or annually, whichever comes first, and replace as necessary; c. Inspect all hoses and belts every 500 hours of operation or annually, whichever comes first, and replace as necessary. Minimize EQUI101 time spent at idle and minimize EQUI101 startup time at startup to a period needed for appropriate and safe loading of EQUI101, not to exceed 30 minutes.


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation Footnote 1 to Table 2c: If EQUI101 is operating during an emergency and it is not possible to shut down EQUI101 in order to perform the work practice requirements on the schedule required in Table 2c of pt. 63, subp. ZZZZ, or if performing the work practice on the required schedule would otherwise pose an unacceptable risk under federal, state, or local law, the work practice can be delayed until the emergency is over or the unacceptable risk under federal, state, or local law has abated. The work practice should be performed as soon as practicable after the emergency has ended or the unacceptable risk under federal, state, or local law has abated. The Permittee must report any failure to perform the work practice on the schedule required and the federal, state or local law under which the risk was deemed unacceptable. [40 CFR 63.6602, Minn. R. 7011.8150]

5.17.15 The Permittee shall at all times comply with the applicable emission limitations, operating limitations, and other requirements in 40 CFR pt. 63, subp. ZZZZ. [40 CFR 63.6605(a), Minn. R. 7011.8150]

5.17.16 At all times the Permittee must operate and maintain EQUI101 in a manner consistent with safety and good air pollution control practices for minimizing emissions. The general duty to minimize emissions does not require the Permittee to make any further efforts to reduce emissions if levels required by 40 CFR pt. 63, subp. ZZZZ have been achieved. Determination of whether such operation and maintenance procedures are being used will be based on information available to the Administrator which may include, but is not limited to, monitoring results, review of operation and maintenance procedures, review of operation and maintenance records, and inspection of EQUI101. [40 CFR 63.6605(b), Minn. R. 7011.8150]

5.17.17 The Permittee shall operate and maintain EQUI101 and after‐treatment control device (if any) according to the manufacturer's emission related written instructions or develop your own maintenance plan which must provide to the extent practicable for the maintenance and operation of EQUI101 in a manner consistent with good air pollution control practice for minimizing emissions. [40 CFR 63.6625(e)((2)), Minn. R. 7011.8150]

5.17.18 The Permittee shall install a non‐resettable hour meter if one is not already installed. [40 CFR 63.6625(f), Minn. R. 7011.8150]

5.17.19 The Permittee shall minimize EQUI101 time spent at idle during startup and minimize EQUI101 startup time to a period needed for appropriate and safe loading of EQUI101, not to exceed 30 minutes. [40 CFR 63.6625(h), Minn. R. 7011.8150]

5.17.20 The Permittee has the option of utilizing an oil analysis


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation program in order to extend the specified oil change requirement in 40 CFR pt. 63, subp. ZZZZ, Table 2c. The oil analysis must be performed at the same frequency specified for changing the oil in Table 2c. The analysis program must at a minimum analyze the following three parameters: Total Base Number, viscosity, and percent water content. The condemning limits for these parameters are as follows: Total Base Number is less than 30 percent of the Total Base Number of the oil when new; viscosity of the oil has changed by more than 20 percent from the viscosity of the oil when new; or percent water content (by volume) is greater than 0.5. If all of these condemning limits are not exceeded, the Permittee is not required to change the oil. If any of the limits are exceeded, the Permittee must change the oil within 2 business days of receiving the results of the analysis; if EQUI101 is not in operation when the results of the analysis are received, the Permittee must change the oil within 2 business days or before commencing operation, whichever is later. The Permittee must keep records of the parameters that are analyzed as part of the program, the results of the analysis, and the oil changes for the engine. The analysis program must be part of the EQUI101 maintenance plan. [40 CFR 63.6625(i), Minn. R. 7011.8150]

5.17.21 The Permittee demonstrate continuous compliance with each operating limitation and other requirements in 40 CFR pt. 63, subp. ZZZZ, Tables 2c and 6. Table 2c: a. Change oil and filter every 500 hours of operation or annually, whichever comes first. b. Inspect air cleaner every 1,000 hours of operation or annually, whichever comes first, and replace as necessary; c. Inspect all hoses and belts every 500 hours of operation or annually, whichever comes first, and replace as necessary. Minimize EQUI101 time spent at idle and minimize EQUI101 startup time at startup to a period needed for appropriate and safe EQUI101 loading, not to exceed 30 minutes. Table 6: a. Work or Management practices: i. Operating and maintaining EQUI101 according to the manufacturer's emission‐related operation and maintenance instructions; or ii. Develop and follow your own maintenance plan which must provide to the extent practicable for the maintenance and operation of EQUI101 in a manner consistent with good air


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation pollution control practice for minimizing emissions. [40 CFR 63.6640(a), Minn. R. 7011.8150]

5.17.22 The Permittee shall report each instance in which it did not meet each applicable operating limitation in Table 2c. These instances are deviations from the 40 CFR pt. 63, subp. ZZZZ operating limitations. These deviations must be reported according to the requirements in 40 CFR Section 63.6650. [40 CFR 63.6640(b), Minn. R. 7011.8150]

5.17.23 The Permittee shall report each instance in which it did not meet any applicable requirement in 40 CFR pt. 63, subp. ZZZZ, Table 8. [40 CFR 63.6640(e), Minn. R. 7011.8150]

5.17.24 The Permittee must operate EQUI101 according to the requirements in 40 CFR 63.6640 paragraphs (f)(1) through (3). In order for EQUI101 to be considered an emergency stationary RICE under 40 CFR pt. 63, subp. ZZZZ, any operation other than emergency operation, maintenance and testing, emergency demand response, and operation in nonemergency situations for 50 hours per year, as described in 40 CFR 63.6640 paragraphs (f)(1) through (3), is prohibited. If the Permittee does not operate EQUI101 according to the requirements in 40 CFR 63.6640 paragraphs (f)(1) through (3), EQUI101 will not be considered an emergency engine under pt. 63, subp. ZZZZ and must meet all requirements for nonemergency engines. [40 CFR 63.6640(f), Minn. R. 7011.8150]

5.17.25 There is no time limit on the use of EQUI101 in emergency situations. [40 CFR 63.6640(f)(1), Minn. R. 7011.8150]

5.17.26 The Permittee may operate EQUI101 for any combination of the purposes specified in 40 CFR 63.6640 paragraphs (f)(2)(i) through (iii) for a maximum of 100 hours per calendar year. Any operation for non‐emergency situations as allowed by 40 CFR 63.6640 paragraph (f)(3) counts as part of the 100 hours per calendar year allowed by 40 CFR 63.6640(f)(2). NOTE: Paragraphs (f)(2)(ii) and (f)(2)(iii) were vacated by the U.S. Court of Appeals for the District of Columbia Circuit on May 1, 2015, but on August 14, 2015, the U.S. Court of Appeals for the District of Columbia Circuit stayed the vacature through May 1, 2016. Therefore, all provisions of 40 CFR 63.6640(f)(2) remain valid and in effect through May 1, 2016 (or until revised by EPA, whichever is earlier). [40 CFR 63.6640(f)(2), Minn. R. 7011.8150]

5.17.27 EQUI101 may be operated for maintenance checks and readiness testing, provided that the tests are recommended by federal, state or local government, the manufacturer, the vendor, the regional transmission organization or equivalent balancing authority and transmission operator, or the insurance company associated with EQUI101. The Permittee may petition the Administrator for approval of additional


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation hours to be used for maintenance checks and readiness testing, but a petition is not required if the Permittee maintains records indicating that federal, state, or local standards require maintenance and testing of EQUI101 beyond 100 hours per calendar year. [40 CFR 63.6640(f)(2)(i), Minn. R. 7011.8150]

5.17.28 EQUI101 may be operated for up to 50 hours per calendar year in non‐emergency situations. The 50 hours of operation in nonemergency situations are counted as part of the 100 hours per calendar year for maintenance and testing and emergency demand response provided in 40 CFR 63.6640(f)(2). The 50 hours per year for non‐emergency situations cannot be used for peak shaving or non‐emergency demand response, or to generate income for a facility to supply power to an electric grid or otherwise supply power as part of a financial arrangement with another entity. [40 CFR 63.6640(f)(3), Minn. R. 7011.8150]

5.17.29 The Permittee shall keep the records described in 40 CFR Section 63.6655(a)(1), (a)(2), and (a)(5). (1) A copy of each submitted notification and report to comply with pt. 63, subp. ZZZZ including all documentation supporting any Initial Notification or Notification of Compliance Status submitted, according to the requirement in Section 63.10(b)(2)(xiv). (2) Records of the occurrence and duration of each malfunction of EQUI101. (5) Records of actions taken during periods of EQUI101 malfunction to minimize emissions in accordance with Section 63.6605(b), including corrective actions to restore EQUI101 to its normal or usual manner of operation. [40 CFR 63.6655(a), Minn. R. 7011.8150]

5.17.30 The Permittee shall keep the records required in pt. 63, subp. ZZZZ, Table 6 item 9, to show continuous compliance with the applicable work or management operating practices (operate and maintain EQUI101 according to the manufacturer's emission‐related operation and maintenance instructions, or, the Permittee can choose to develop and follow a maintenance plan which must provide to the extent practicable for maintenance and operation of EQUI101 in a manner consistent with good air pollution control practice for minimizing emissions). [40 CFR 63.6655(d), Minn. R. 7011.8150]

5.17.31 The Permittee shall keep records of the maintenance conducted on EQUI101 in order to demonstrate that it operated and maintained EQUI101 according to its own maintenance plan. [40 CFR 63.6655(e)(2), Minn. R. 7011.8150]

5.17.32 The Permittee shall keep records of EQUI101 hours of operation recorded through the non‐resettable hour meter.


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation The Permittee shall document how many hours are spent for emergency operation, including what classified the operation as emergency and how many hours are spent for non‐emergency operation. [40 CFR 63.6655(f)(1), Minn. R. 7011.8150]

5.17.33 a) The Permittee shall keep records in a form suitable and readily available for expeditious review according to Section 63.10(b)(1). (b) As specified in Section 63.10(b)(1), the Permittee shall keep each record for 5 years following the date of each occurrence, measurement, maintenance, corrective action, report, or record. (c) The Permittee shall keep each record readily accessible in hard copy or electronic form for at least 5 years after the date of each occurrence, measurement, maintenance, corrective action, report, or record, according to Section 63.10(b)(1). [40 CFR 63.6660, Minn. R. 7011.8150]

5.17.34 The Permittee shall comply with the requirements from 40 CFR pt. 63, subp. ZZZZ prescribed in this permit. For any revision(s) to subp. ZZZZ requirement(s) not yet incorporated into this permit, the Permittee shall comply with the revised subp. ZZZZ requirement(s) in place of such obsolete requirement(s) in this permit. The Permittee shall submit an application in accordance with the requirements of Minn. R. 7007.1150 through Minn. R. 7007.1500 as soon as practicable after any subp. ZZZZ revision that renders any subp. ZZZZ permit requirement obsolete, to incorporate appropriate changes to the subp. ZZZZ requirements in the permit. [Minn. R. 7007.0800, subp. 2]

TREA 4 CE007 Tripper Floor

baghouse; CE 007

5.18.1 TREA04 is a low temperature fabric filter that is listed control equipment under Minn. R. 7011.0060 to 7011.0080. The Permittee shall vent emissions from EQUI89 to TREA04 whenever EQUI89 is operating, and operate and maintain TREA04 at all times that any emissions are vented to TREA04. The Permittee shall document periods of TREA04 non‐operation. [Minn. R. 7011.0075, subp. 1]

5.18.2 The Permittee shall operate and maintain TREA04 such that it achieves a control efficiency for Total Particulate Matter >= 99 percent control efficiency. [Minn. R. 7011.0070, subp. 1(A)]

5.18.3 The Permittee shall operate and maintain TREA04 such that it achieves a control efficiency for PM < 10 micron >= 93 percent control efficiency. [Minn. R. 7011.0070, subp. 1(A)]

5.18.4 The Permittee shall operate and maintain TREA04 such that it achieves a control efficiency for PM < 2.5 micron >= 93 percent


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation control efficiency. [Minn. R. 7007.0800, subp. 2&14]

5.18.5 Visible Emissions: The Permittee shall check TREA04 stack STRU07 for any visible emissions once each day of operation during daylight hours. [Minn. R. 7011.0080]

5.18.6 Recordkeeping of Visible Emissions Observations: The Permittee shall record the time and date of each visible emission inspection and whether or not any visible emissions were observed. [Minn. R. 7011.0080]

5.18.7 TREA04 is a listed control equipment type under Minn. R. 7011.0060 to 7011.0080. The Permittee shall vent emissions from EQUI04 to TREA04 whenever EQUI04 operates, and operate and maintain TREA04 at all times that any emissions are vented to TREA04. The Permittee shall document periods of non‐operation of TREA04. [Minn. R. 7011.0075, subp. 1]

5.18.8 Corrective Actions: The Permittee shall take corrective action as soon as possible if any of the following occur: ‐ visible emissions are observed; ‐ 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 TREA04. [Minn. R. 7007.0800, subp. 14, Minn. R. 7007.0800, subp. 4, Minn. R. 7007.0800, subp. 5]

5.18.9 The Permittee shall maintain TREA04 according to the manufacturer's specification, and shall conduct inspections and maintain documentation of those actions as required by Minn. R. 7011.0075, subp. 2(A) to 2(I). [Minn. R. 7011.0075, subp. 2]

TREA 10 CE004 Fly Ash Silo

baghouse; CE 004

5.19.1 TREA10 is a low temperature fabric filter. The Permittee shall vent emissions from EQUI88 (fly ash silo) to TREA10 (fly ash silo fabric filter) whenever EQUI88 operates, and operate and maintain TREA10 at all times that any emissions are vented to TREA10. The Permittee shall document periods of non‐operation of TREA10. [Minn. R. 7007.0800, subp. 2&14]

5.19.2 The Permittee shall operate and maintain TREA10 such that it achieves a control efficiency for Total Particulate Matter >= 99 percent control efficiency. [Minn. R. 7007.0800, subp. 2&14]

5.19.3 The Permittee shall operate and maintain TREA10 such that it


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation achieves a control efficiency for PM < 10 micron >= 93 percent control efficiency. [Minn. R. 7007.0800, subp. 2&14]

5.19.4 The Permittee shall operate and maintain TREA10 such that it achieves a control efficiency for PM < 2.5 micron >= 87 percent control efficiency. [Minn. R. 7007.0800, subp. 2&14]

5.19.5 The Permittee shall operate and maintain TREA10 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]

5.19.6 Visible Emissions: The Permittee shall check the TREA10 stack (STRU06) for any visible emissions once each day of operation during daylight hours. [Minn. R. 7007.0800, subps. 4‐5]

5.19.7 Recordkeeping of Visible Emissions: The Permittee shall record the time and date of each STRU06 visible emission inspection and whether or not any visible emissions were observed. [Minn. R. 7007.0800, subps. 4‐5]

5.19.8 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 return the pressure drop to within the permitted range, 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. 14, Minn. R. 7007.0800, subp. 4, Minn. R. 7007.0800, subp. 5]

5.19.9 Periodic Inspections: At least once per calendar quarter, or more frequently as required by the manufacturer's specifications, the Permittee shall inspect the control equipment components. The Permittee shall maintain a written record of these inspections. [Minn. R. 7007.0800, subp. 14, Minn. R. 7007.0800, subp. 4, Minn. R. 7007.0800, subp. 5]

TREA 18 CE019 Crusher

baghouse; CE 019

5.20.1 TREA18 is a low temperature fabric filter. The Permittee shall vent emissions from EQUI03 (coal crusher) to TREA18 (coal crusher fabric filter) whenever EQUI03 operates, and operate and maintain TREA018 at all times that any emissions are vented to TREA18. The Permittee shall document periods of


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation non‐operation of TREA18. [Title I Condition: Avoid major modification under 40 CFR 52.21(b)(1)(i) and Minn. R. 7007.3000]

5.20.2 The Permittee shall operate and maintain control equipment such that it achieves a control efficiency for Total Particulate Matter >= 99 percent control efficiency. [Title I Condition: Avoid major modification under 40 CFR 52.21(b)(1)(i) and Minn. R. 7007.3000]

5.20.3 The Permittee shall operate and maintain control equipment such that it achieves a control efficiency for PM < 10 micron >= 93 percent control efficiency. [Title I Condition: Avoid major modification under 40 CFR 52.21(b)(1)(i) and Minn. R. 7007.3000]

5.20.4 The Permittee shall operate and maintain control equipment such that it achieves a control efficiency for PM < 2.5 micron >= 93 percent control efficiency. [Title I Condition: Avoid major modification under 40 CFR 52.21(b)(1)(i) and Minn. R. 7007.3000]

5.20.5 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]

5.20.6 Visible Emissions: The Permittee shall check the TREA18 stack (STRU11) for any visible emissions once each day of operation during daylight hours. [Minn. R. 7007.0800, subp. 4&5, Title I Condition: Avoid major modification under 40 CFR 52.21(b)(1)(i) and Minn. R. 7007.3000]

5.20.7 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, Title I Condition: Avoid major modification under 40 CFR 52.21(b)(1)(i) and Minn. R. 7007.3000]

5.20.8 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. 14, Minn. R. 7007.0800, subp. 4, Minn. R.


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 7007.0800, subp. 5]

5.20.9 Periodic Inspections: At least once per calendar quarter, or more frequently as required by the manufacturer, the Permittee shall inspect the control equipment components. The Permittee shall maintain a written record of these inspections. [Minn. R. 7007.0800, subp. 14, Minn. R. 7007.0800, subp. 4, Minn. R. 7007.0800, subp. 5]

TREA 29 CE027 Bottom Ash Silo

baghouse; CE 027

5.21.1 TREA29 is a low temperature fabric filter that is listed control equipment under Minn. R. 7011.0060 to 7011.0080. The Permittee shall vent emissions from EQUI99 to TREA29 whenever EQUI99 operates, and operate and maintain TREA29 at all times that any emissions are vented to TREA29. The Permittee shall document periods of non‐operation of TREA29. [Minn. R. 7011.0075, subp. 1]

5.21.2 The Permittee shall operate and maintain TREA29 so that it achieves a control efficiency for Total Particulate Matter >= 99 percent control efficiency. [Minn. R. 7011.0070, subp. 1(A)]

5.21.3 The Permittee shall operate and maintain TREA29 so that it achieves a control efficiency for PM < 10 micron >= 93 percent control efficiency. [Minn. R. 7011.0070, subp. 1(A)]

5.21.4 The Permittee shall operate and maintain TREA29 so that it achieves a control efficiency for PM < 2.5 micron >= 87 percent control efficiency. [Minn. R. 7007.0800, subp. 2&14]

5.21.5 Visible Emissions: The Permittee shall check the fabric filter stack (STRU12) for any visible emissions once each day of operation during daylight hours. [Minn. R. 7011.0080]

5.21.6 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. 7011.0080]

5.21.7 Corrective Actions: The Permittee shall take corrective action as soon as possible if any of the following occur: ‐ visible emissions are observed; or ‐ TREA29 or any of its components are found during any inspection 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 TREA29. [Minn. R. 7007.0800, subp. 14, Minn. R. 7007.0800, subp. 4, Minn. R. 7007.0800, subp. 5]


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 5.21.8 The Permittee shall maintain TREA29 according to the

manufacturer's specifications, shall conduct inspections, and maintain documentation of those actions as required by Minn. R. 7011.0075, subp. 2(A) to 2(I). [Minn. R. 7011.0075, subp. 2]

TREA 30 CE028 Ash Loadout

baghouse; CE 028

5.22.1 TREA30 is a low temperature fabric filter that is listed control equipment under Minn. R. 7011.0060 to 7011.0080. The Permittee shall vent emissions from EQUI100 to TREA30 whenever EQUI100 operates, and operate and maintain TREA30 at all times that any emissions are vented to TREA30. The Permittee shall document periods of non‐operation of TREA30. [Minn. R. 7011.0075, Title I Condition: Avoid major modification under 40 CFR 52.21(b)(1)(i) and Minn. R. 7007.3000]

5.22.2 The Permittee shall operate and maintain TREA30 such that it achieves a control efficiency for Total Particulate Matter >= 99 percent control efficiency. [Minn. R. 7011.0070, subp. 1(A)]

5.22.3 The Permittee shall operate and maintain TREA30 such that it achieves a control efficiency for PM < 10 micron >= 93 percent control efficiency. [Minn. R. 7011.0070, subp. 1(A)]

5.22.4 The Permittee shall operate and maintain TREA30 such that it achieves a control efficiency for PM < 2.5 micron >= 93 percent control efficiency. [Title I Condition: Avoid major modification under 40 CFR 52.21(b)(1)(i) and Minn. R. 7007.3000]

5.22.5 Visible Emissions: The Permittee shall check the TREA30 stack STRU13 for any visible emissions once each day of operation during daylight hours. [Minn. R. 7011.0080, Title I Condition: Avoid major modification under 40 CFR 52.21(b)(1)(i) and Minn. R. 7007.3000]

5.22.6 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. 7011.0080, Title I Condition: Avoid major modification under 40 CFR 52.21(b)(1)(i) and Minn. R. 7007.3000]

5.22.7 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.


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 7007.0800, subp. 14, Minn. R. 7007.0800, subp. 4, Minn. R. 7007.0800, subp. 5]

5.22.8 The Permittee shall maintain TREA30 according to the manufacturer's specification, shall conduct inspections, and maintain documentation of those actions as required by Minn. R. 7011.0075, subp. 2(A) to 2(I). [Minn. R. 7011.0075, subp. 2]

6. Submittal/action requirements

This section lists most of the submittals required by this permit. Please note that some submittal requirements may appear in the Limits and Other Requirements section, or, if applicable, within a Compliance Schedule section.

Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation TFAC 2 03100001 Minnesota Power

‐ Taconite Harbor Energy Center

6.1.1 The Permittee shall submit an application for permit reissuance : Due 180 calendar days before Permit Expiration Date. [Minn. R. 7007.0400, subp. 2]

6.1.2 The Permittee shall submit a compliance certification : Due annually, by the 31st of January (for the previous calendar year). Submit the certification on a form approved by the Commissioner. This certification covers all deviations experienced during the calendar year. [Minn. R. 7007.0800, subp. 6(C)]

6.1.3 The Permittee shall submit a semiannual deviations report : Due semiannually, by the 30th of January and July. 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. [Minn. R. 7007.0800, subp. 6(A)(2)]

6.1.4 The Permittee shall submit excess emission/downtime report : Due by 30 days after the end of each calendar quarter following permit issuance. 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. The EER must be submitted even if there were no excess emissions, downtime or bypasses during the quarter. [Minn. R. 7017.1110, subp. 1‐2]

COMG 2 GP001 Two 900

mmBtu/hr


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation tangentially‐fired dry bottom coal‐fired boilers; REQUIREMENTS APPLY INDIVIDUALLY TO EACH COMG2 BOILER UNLESS OTHERWISE NOTED. Refer to EQUI 64 and EQUI5 for additional applicable requirements.

6.2.1 Filterable Particulate Matter : The Permittee shall conduct performance test : Due by the end of each calendar year commencing calendar year (CY) 2014 and continuing thereafter. The Permittee shall conduct stack tests each year on each electric generating unit at the facility to determine compliance with the 0.030 lb/mmBtu (3‐hour average) filterable PM emission limit established by Consent Decree paragraph 125, unless the unit to be tested is retired, refueled, or repowered by June 30 of the same CY. To determine compliance with the filterable PM emission limit, the Permittee shall use EPA Method 5 (filterable portion only) or a PM stack testing method specified in and allowed by applicable Minnesota SIP provision(s). Each test shall consist of three separate runs performed under representative operating conditions not including periods of startup, shutdown, or malfunction. The sampling time for each run shall be at least 60 minutes and the volume of each run shall be at least 0.85 dry standard cubic meters (30 dry standard cubic feet). The Permittee shall calculate the PM Emission Rate from the stack test results in accordance with 40 CFR Section 60.8(f). The results of each PM stack test shall be submitted to EPA and MPCA within 60 Days following completion of such test. Commencing in CY 2014, and continuing annually thereafter, the Permittee shall also conduct a PM stack test for condensable PM on each electric generating unit at the facility as required by Consent Decree paragraph 129, using the reference methods and procedures set forth at 40 CFR Part 51, Appendix M, Method 202, unless the Unit is retired, refueled, or repowered by June 30 of the same calendar year. Each test shall consist of three separate runs performed under representative operating conditions not including periods of startup, shutdown, or malfunction. The sampling time for each run shall be at least


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 60 minutes and the volume of each run shall be at least 0.85 dry standard cubic meters (30 dry standard cubic feet). The Permittee shall calculate the number of pounds of condensable PM emitted per million BTU of heat input (lb/mmBtu) from the stack test results in accordance with 40 CFR Section 60.8(f). The results of the PM stack test conducted pursuant to Consent Decree paragraph 129 shall not be used for the purpose of determining compliance with the Consent Decree PM emission limit. The results of each PM stack test shall be submitted to EPA and MPCA within 60 Days following completion of such test. The annual performance test requirement imposed on the Permittee by Consent Decree Section VI.H may be satisfied by stack tests conducted by the Permittee as may be required by its permits from the State of Minnesota for any year that such stack tests are required under the permits. The Permittee may perform testing every other year, rather than every year, provided that the two most recently completed test results conducted in accordance with the methods and procedures specified in the Consent Decree demonstrate that the PM emissions are equal to or less than 0.015 lb/mmBtu. The Permittee shall perform testing every year, rather than every other year, beginning in the year immediately following any test result demonstrating that the PM emissions are greater than 0.015 lb/mmBtu. The Permittee shall implement the same testing frequency for condensable PM as allowed by this permit for filterable PM. [CAAA of 1990, Minn. R. 7007.0100, subp. 7, Minn. R. 7007.0800, subp. 1&2, Minn. Stat. 116.07, subd. 4a&9, Title I Condition: 40 CFR 52.21]

COMG 6 CEMS & COMS

requirements Part 75 and SIP SO2 & NOx CEMS and COMS Requirements for STRU1 & STRU2 ‐ Requirements apply individually to each CEMS and each COMS on each stack unless otherwise noted. PM and Hg CEMS requirements are located in COMG7.

6.3.1 The Permittee shall conduct linearity and leak check : Due by the end of each QA operating quarter. Conduct the linearity


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation check according to 40 CFR pt. 75, Appendix B, Section 2.2.1 and Appendix A, Section 6.2, and conduct the leak check according to 40 CFR pt. 75, Appendix B, Section 2.2.2. Perform a leak check at least once during each QA operating quarter with no less than 30 days between each leak check. A QA operating quarter is a calendar quarter in which there are at least 168 unit operating hours (as defined in Section 72.2). [40 CFR 75.21(a)(1), 40 CFR pt. 75, Appendix B, Sec. 2.2]

6.3.2 The Permittee shall conduct CEMS relative accuracy test audit (RATA) : Due semiannually. The Permittee shall perform a RATA on all CEMS required by the Acid Rain Program once every two successive QA operating quarters (calendar quarter in which there are at least 168 unit operating hours), according to the requirements at 40 CFR pt. 75, Appendix B, Section 2.3.1 on all CEMS required by the Acid Rain Program. RATAs 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, Sections 2.3.1.2(a) through 2.3.1.2(i) are met. [40 CFR pt. 75, App. B, Sec. 2.3.1]

6.3.3 The Permittee shall conduct COMS calibration error audit : Due by the end of each calendar half‐year with audits conducted at least three months apart but no more than eight months apart except that a calibration error audit need not be conducted during any semiannual period in which the emission unit operated less than 24 hours. The calibration error audit shall be conducted according to the procedures in 40 CFR pt. 60, Appendix B, Performance Specification 1, or Appendix F, Procedure 3. [40 CFR 75.21(b), Minn. R. 7007.0800, subp. 4(D), Minn. R. 7017.1210, subp. 3]

EQUI 3 EU011 Crusher and

Related Transfer Points; EU 011

6.4.1 Opacity : The Permittee shall conduct a performance test : Due 60 calendar days after Permit Issuance Date every 60 months. This test shall be conducted within 60 calendar days after permit issuance, and then at five‐year intervals thereafter. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp. 8, using EPA Reference Method 9, or other method approved by MPCA in the performance test plan approval. Testing conducted during the 60‐day period before the performance test due date satisfies this test requirement and will not reset the test due date for future testing as required by


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation this permit, the most recently approved Performance Test Frequency Plan, or a Notice of Compliance letter. Testing conducted more than 60 days prior to the performance test due date satisfies this test requirement but will reset the performance test due date for future testing. [Minn. R. 7017.2020, subp. 1]


002

6.5.1 Total Particulate Matter : The Permittee shall conduct performance test : Due after 05/07/2015 every 36 months. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp. 8, using EPA Reference Method 5, or other method approved by MPCA in the performance test plan approval. Testing conducted during the 60‐day period before the performance test due date satisfies this test requirement and will not reset the test due date for future testing as required by this permit, the most recently approved Performance Test Frequency Plan, or a Notice of Compliance letter. Testing conducted more than 60 days prior to the performance test due date satisfies this test requirement but will reset the performance test due date for future testing. This testing may be used to meet the calendar year filterable PM testing required by the 2014 consent decree as authorized by CD paragraph 130. [Minn. R. 7017.2020, subp. 1]

6.5.2 PM < 10 micron : The Permittee shall conduct performance test : Due after 05/07/2015 every 60 months. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp. 8, using EPA Reference Method 5 or 201A, and 202, or other method(s) approved by MPCA in the performance test plan approval. Testing conducted during the 60‐day period before the performance test due date satisfies this test requirement and will not reset the test due date for future testing as required by this permit, the most recently approved Performance Test Frequency Plan, or a Notice of Compliance letter. Testing conducted more than 60 days prior to the performance test due date satisfies this test requirement but will reset the performance test due date for future testing. This testing may be used to meet the calendar year condensable PM testing required by the 2014 consent decree as authorized by CD paragraph 130. [Minn. R. 7017.2020, subp. 1]



Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 001

6.6.1 Total Particulate Matter : The Permittee shall conduct performance test : Due after 05/06/2015 every 60 months. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp. 8, using EPA Reference Method 5, or other method approved by MPCA in the performance test plan approval. Testing conducted during the 60‐day period before the performance test due date satisfies this test requirement and will not reset the test due date for future testing as required by this permit, the most recently approved Performance Test Frequency Plan, or a Notice of Compliance letter. Testing conducted more than 60 days prior to the performance test due date satisfies this test requirement but will reset the performance test due date for future testing. This testing may be used to meet the calendar year filterable PM testing required by the 2014 consent decree as authorized in CD paragraph 130. [Minn. R. 7017.2020, subp. 1]


7. Appendices

Appendix A: Insignificant Activities and General Applicable Requirements


The table below lists the insignificant activities that are currently at the Facility and their associated general applicable requirements.

Minn. R. Rule description of the activity General applicable requirement Minn. R. 7007.1300, subp. 3(B)(2) Indirect heating equipment with a capacity

less than 420,000 Btu/hour, etc. Landfill shop 225,000 Btu/hr propane‐fired furnace

PM <= 0.6 or 0.4, depending on year constructed Opacity <= 20% with exceptions (Minn. R. 7011.0510/0515)

Minn. R. 7007.1300, subp. 3(B)(2) Indirect heating equipment with a capacity less than 420,000 Btu/hour, etc. Landfill shop 361,000 Btu/hr propane‐fired heated pressure washer

PM <= 0.6 or 0.4, depending on year constructed Opacity <= 20% with exceptions (Minn. R. 7011.0510/0515)

Minn. R. 7007.1300, subp. 3(G) Emissions from a laboratory, as defined in Minn. R. 7007.1300, subp. 3(G)

PM, variable depending on airflow Opacity <= 20% (Minn. R. 7011.0710/0715)

Minn. R. 7007.1300, subp. 3(H)(3) Brazing, soldering or welding equipment PM, variable depending on airflow Opacity <= 20% (Minn. R. 7011.0710/0715)

Minn. R. 7007.1300, subp. 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


Minn. R. 7008.4110 Equipment venting PM/PM10 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 Three reagent storage silos



Appendix B: Acid Rain Permit Application


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 bottom wall‐fired, “T” for tangentially 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



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 (RLi x HIi) [Rli x HIi] i=l i=l ________________ < __________________ n n HIi 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.


Appendix C: SO2 Modeling Parameters


Minnesota Power Taconite Harbor Energy Center 1‐hour SO2 Modeling Parameters

Permit AERMOD X1 Y1 Base Elev

Emission Rate

Emission Rate Height Exit Temp Exit Vel Diam Flow Rate

ID ID [m] [m] [m] [lb/hr] [g/sec] [m] [K] [m/s] [m] [ACFM]

EQUI64 STRU1 657,243.240 5,266,255.880 189.97 330.48 41.64 67.06 449.261 20.90928 3.02 323,595

EQUI5 STRU2 657,228.670 5,266,242.280 189.98 330.48 41.64 67.06 449.261 20.90928 3.02 323,595

EQUI65 STRU3 657,215.070 5,266,229.650 189.98 0 0 67.06 435.93 25.738 3.02 390,000


Appendix D: Fugitive Emissions Control Plan


Fugitive Emissions Control Plan

Minnesota Power-Taconite Harbor Energy Center Air Emissions Permit 03100001, AQ# 48A

Revised Plan Date: February 2, 2016




Table of Contents:

I. Contact and Site Description……..…………………………………………..…..3

II. Potential Fugitive Dust Sources and Active Control Measures……4 ‐13

1) FS001/FUGI12 Pellet Drop From Railcars into Dock Storage Bins (Cliffs Erie) 2) FS002/FUGI2 Coal Storage Pile 3) FS003/FUGI13 Limestone Storage Pile 4) FS004/FUGI1 Coal/Limestone Materials Handling 5) FS005/FUGI6 Ship Loading of Taconite Pellets (Cliffs Erie) 6) FS006/FUGI8 Railcar Materials Loading (Cliffs Erie) 7) FS007/FUGI7 Truck Ash Hauling-Unpaved Roads 8) FS008/FUGI5 Ash Storage Pile-Wind Erosion 9) FS009/FUGI10 Activated Carbon-Paved Roads 10) FS010/FUGI11 Hydrated Lime Truck Hauling-Paved Roads 11) FS011/FUGI9 Molten Sulfur Truck Hauling-Paved Roads 12) FS012/FUGI3 Ammonia Truck Hauling-Paved Roads 13) FS013/FUGI4 Urea Truck Hauling-Paved Roads 14) FS014/FUGI14 Sodium Bicarbonate Hauling-Paved Roads 15) FS015/FUGI15 Ash Hauling-Paved Roads Figures…………………………………………………………………………………………………….14‐16 1) Site Map 2) Exhibit A, B, C 3) Process Flow Diagram




I. Contact and Site Description

Plan Date: January 25, 2016 Contacts and Location:

Site Brian Smith Office: (218) 406-6881

Cell: (218) 370-8167

Facility Name

Taconite Harbor Energy Center

Facility Address 8124 West highway 61

Schroeder, MN. 55613 Cook County

Type of Activity Electrical Generation

Site Description: Minnesota Power’s Taconite Harbor Energy Center consists of three 75 megawatt (net) coal-fired Units (Note: Unit 3 was retired in 2015). 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. Cliffs Erie LLC is a co-permitee with Minnesota Power. Cliffs Erie owns the dock area taconite handling facility and closed landfill adjacent to the Taconite Harbor Energy Center; related fugitive sources are 001, 005 and 006.




Description of Fugitive Dust Emissions Sources: Fugitive sources at the facility are mainly related to the handling/transporting of bulk materials. This includes iron units (i.e. taconite pellets, taconite pellet chips and fines), coal, fluxstone/limestone, and boiler ash. Material handling activities include such things as rail car loading and unloading, ship loading and unloading, coal yard storage and handling, and coal ash disposal. In addition, wind erosion of coal, limestone and ash storage piles may occur. Other sources of fugitive dusts are related to vehicular traffic typical of an industrial plant facility. However, the majority of the roads at this site are paved, keeping fugitive emission pollution to a minimal level. Fugitive Sources: Reasonable control measures are listed for each source category in the following sections. 1) FS001/FUGI12 Pellet Drop From Railcars into Dock Storage Bins (Cliffs Erie) 2) FS002/FUGI2 Coal Storage Pile 3) FS003/FUGI13 Limestone Storage Pile 4) FS004/FUGI1 Coal/Limestone Materials Handling 5) FS005/FUGI6 Ship Loading of Taconite Pellets (Cliffs Erie) 6) FS006/FUGI8 Railcar Materials Loading (Cliffs Erie) 7) FS007/FUGI7 Truck Ash Hauling-Unpaved Roads 8) FS008/FUGI5 Ash Storage Pile-Wind Erosion 9) FS009/FUGI10 Activated Carbon-Paved Roads 10) FS010/FUGI11 Hydrated Lime Truck Hauling-Paved Roads 11) FS011/FUGI9 Molten Sulfur Truck Hauling-Paved Roads 12) FS012/FUGI3 Ammonia Truck Hauling-Paved Roads 13) FS013/FUGI4 Urea Truck Hauling-Paved Roads 14) FS014/FUGI14 Sodium Bicarbonate Hauling-Paved Roads 15) FS015/FUGI15 Ash Hauling-Paved Roads




II. Potential Fugitive Dust Sources and Control Measures 1) FS001/FUGI12: Pellet Drop From Railcars into Dock Storage Bins (Cliffs Erie) Fugitive Material: associated with pellet drop Additional information:

Iron units (i.e., taconite pellets, pellet chips and fines) are delivered by rail from Hoyt Lakes and bottom dumped into 25 open dock storage bins (Exhibit A). Fugitive dust is controlled during product drop from rail cars into the dock storage bins using bin water sprays (Exhibit B). The generation of fugitive dust from handling product at the dock is a function of moisture content of the product as received at the dock. If necessary, the product car spray rack located at Taconite Harbor (Exhibit C) can be used to add water to maintain moisture content and control fugitive dust emissions. Moisture content is also maintained prior to rail cars arriving at the dock using product yard spray monitors and product car sprays located in Hoyt Lakes. Summary of Reasonably Available Control Measures: Control Measure

Control Action

Bin Water Sprays

Sprays used as necessary (rail cars to dock bins)

Car Water Sprays

Sprays used as necessary (cars at receiving)

Yard Water Sprays

Sprays used as necessary (in transit Hoyt Lakes)

Weather Natural weather conditions; rain, snow, subfreezing




temperatures

2) FS002/FUGI2: Coal Storage Pile Material: Coal Dust Additional information:

Due to the size of the coal storage pile, wind blowing across the pile can create fugitive dust. In order to combat this, when temperatures permit, the slopes of the pile will be sprayed with water to reduce dust entrainment from the wind. In addition, the storage pile will be routinely compacted which has been shown to be effective in reducing fugitives. And in winter months, dust emissions are naturally reduced by the surface freezing of the free moisture associated with the coal. Fuels staff performs daily visible emissions checks, these preventive inspections are logged in the electronic fuels log. Corrective actions are taken as necessary. Summary of Reasonably Available Control Measures: Control Measure

Control Action

Reduce Wind Exposure

Adjacent buildings/structures/vegetation

Water Sprays

Sprays used as necessary

Weather

Natural weather conditions; rain, snow, subfreezing temperatures

Moisture Content

Coal moisture content typically ~25%

Compaction

Coal is routinely compacted (by normal dozer use)

3) FS003/FUGI13: Limestone Storage Pile Material: Limestone Dust Additional information:

Fluxstone/limestone is delivered to the site via ship and back-hauled from Taconite Harbor to Hoyt Lakes via rail car. Occasionally, some limestone is used at THEC for housekeeping/landscaping purposes. Limestone handling and storage has not been a significant source of fugitive dust emissions in the past. Handling typically includes loading of limestone into rail cars for transport to Hoyt Lakes and stockpile




maintenance. Handling is typically accomplished using a front-end loader. Fugitive dust generated during loading is controlled by application of water if needed. No control measures will be used during storage of limestone unless fugitive emissions are observed. Summary of Reasonably Available Control Measures: Control Measure Control Action

Water Application



Adjacent buildings/structures next to the dump area.

Weather Natural weather conditions; rain, snow, subfreezing temperatures

4) FS004/FUGI1: Coal Materials Handling Material: Coal Dust Additional information:

Coal arrives in self-unloading ships that typically transport materials on the Great Lakes. The coal usually arrives in approximately 60,000-ton consignments. It is off-loaded from the vessel via conveyor into a catch hopper (D1 Hopper). This hopper transfers the coal onto a series of conveyors (D1, D2, and D3) which deposit the material into a surge stockpile area. The coal is then either pushed by a bulldozer into a hopper feeding the D4 conveyor for transfer to the power plant bunkers, the D7 and D8 conveyors for transfer into railcars or to the main coal storage area (approximately 650,000-ton capacity).

THEC normally burns a western sub-bituminous coal, which contains around 25% moisture. A chemical dust suppressant is applied to the coal at the coal supplier’s facility when the coal is unloaded from rail cars and again when coal is loaded into ships for shipment to THEC. In addition, when a ship unloads coal, water is added by the ship operator at different points in the unloading operation (ship’s conveyor belt and ship bunker clean out). All this water plus the moisture inherent in the coal normally results in limited dust emissions during coal handling operations. MPCA Form GI-05A indicates that material with moisture content greater than 6% can claim 99% control efficiency. Fuels staff performs daily visible emissions checks, these preventive inspections are logged in the electronic fuels log. Corrective actions are taken as necessary.




Summary of Reasonably Available Control Measures: Control Measure

Control Action



Chemical Suppressant

Periodically applied at supplier and in transit

Water Sprays

May be applied at ship off loading

Weather


Moisture Content Coal moisture content typically ~25% 5) FS005/FUGI6: Ship Loading of Taconite Pellets (Cliffs Erie) Material: Iron Pellets Additional information:

Each dock storage bin has a retractable conveyor beneath it, which carries, and deposits iron units (product) into a ship (Exhibit A). Existing sprays (CE005; Exhibit B) at the dock conveyor feed point (FS001) are sufficient to control dust at the load out conveyor to ship transfer point. Summary of Reasonably Available Control Measures: Control Measure Control Action Conveyor Water Sprays Sprays used as necessary 6) FS006/FUGI8: Railcar Materials Loading (Cliffs Erie)




Material: Coal Dust Additional information:

Coal is loaded into rail cars from the coal storage area for transportation to Hoyt Lakes. Coal from the stockpile is loaded onto the D7 conveyor using a bulldozer then transferred via the D8 conveyor directly to rail cars. Rail car material loading has not been a significant source of fugitive dust emissions in the past. However, rail car loading is monitored and water can be applied if necessary to control fugitive dust. Summary of Reasonably Available Control Measures: Control Measure Control Action Water Application Water sprays used as necessary 7) FS007/FUGI7: Truck Ash Hauling-Unpaved Roads Material: Road Dusts Additional information:

Ash disposal is accomplished by the hauling of wetted ash in covered trucks over a two mile long unpaved road (covered with Class 5 gravel). In order to control any fugitive emissions caused from the trucks, a chemical dust suppressant is applied once per year. In addition, water is applied to the road as needed to control dust. Summary of Reasonably Available Control Measures: Control Measure Control Action

Chemical Suppressant Applied once per year (invoiced) Reduce Speed

10 mph speed limit signs are posted

Other

Roads are surfaced with Class V gravel to minimize fugitive dust formation




Weather


8) FS008/FUGI5: Ash Storage Pile-Wind Erosion Material: Ash Dust Additional information:

Once the haul trucks dump their loads of ash onto the storage pile, a bulldozer is used to spread the ash over the pile. Normally the just-dumped ash is still wet from being loaded into the trucks, so limited dust is created. However, truck and bulldozer traffic on top of the dried out ash storage pile, in addition to wind erosion, does create some fugitive dust. To control this entrainment, the pile is routinely compacted and water from the ash cell leachate collection system is sprayed over the pile weather permitting. In the winter months, there is also snow cover, which aids in the prevention of fugitive dust. Fuels staff performs daily visible emissions checks, these preventive inspections are logged in the electronic fuels log. Corrective actions are taken as necessary. Summary of Reasonably Available Control Measures: Control Measure

Control Action

Water Application




Compaction

Ash is routinely compacted (by normal dozer use)


9) FS009/FUGI10: Activated Carbon Truck Hauling-Paved Roads Material: Road Dusts Additional information:

Trucks deliver the mercury reagent by using the main plant paved access road to a storage building located on the south side of the power plant building. The access road is inspected daily for fugitive dust. The road surface is typically swept at least once per week using a mechanical road sweeper.




Reasonably Available Control Measures Control Measure Control Action Street Sweeper (seasonal) Paved roads are typically swept weekly Reduce Speed 10 mph speed limit signs are posted Reduce Wind Exposure Adjacent buildings/structures/vegetation Weather Natural weather conditions; rain, snow, subfreezing

temperatures 10) FS010/FUGI11: Hydrated Lime Truck Hauling-Paved Roads Material: Road Dusts Additional information:

Trucks deliver hydrated lime by using the main plant paved access road to a storage building located on the south side of the power plant building. The access road is inspected daily for fugitive dust. The road surface is swept at least once per week using a mechanical road sweeper. Reasonably Available Control Measures Control Measure Control Action Street Sweeper (seasonal) Paved roads are typically swept weekly Reduce Speed 10 mph speed limit signs are posted Reduce Wind Exposure Adjacent buildings/structures/vegetation Weather Natural weather conditions; rain, snow, subfreezing

temperatures 11) FS011/FUGI9: Molten Sulfur Truck Hauling-Paved Roads Material: Road Dusts Additional information:




Trucks deliver molten sulfur by using the main plant paved access road to a storage tank located on the east side of the power plant building. The access road is inspected daily for fugitive dust. The road surface is swept at least once per week using a mechanical road sweeper. Summary of Reasonably Available Control Measures: Control Measure Control Action Street Sweeper (seasonal) Paved roads are typically swept weekly Reduce Speed 10 mph speed limit signs are posted Reduce Wind Exposure Adjacent buildings/structures/vegetation Weather Natural weather conditions; rain, snow, subfreezing

temperatures 12) FS012/FUGI3: Ammonia Truck Hauling-Paved Roads Material: Road Dusts Additional information:

Trucks deliver the anhydrous ammonia by using the main plant paved access road to a storage tank located on the west side of the power plant screen house. The access road is inspected daily for fugitive dust. The road surface is swept at least once per week using a mechanical road sweeper. Summary of Reasonably Available Control Measures: Control Measure Control Action Street Sweeper (seasonal) Paved roads are typically swept weekly Reduce Speed 10 mph speed limit signs are posted Reduce Wind Exposure Adjacent buildings/structures/vegetation Weather Natural weather conditions; rain, snow, subfreezing

temperatures 13) FS013/FUGI4: Urea Truck Hauling-Paved Roads




Material: Road Dusts Additional information:

Trucks deliver urea by using the main plant paved access road to a storage building located on the south side of the power plant building. The access road is inspected daily for fugitive dust. The road surface is swept at least once per week using a mechanical road sweeper. Summary of Reasonably Available Control Measures: Control Measure Control Action Street Sweeper (seasonal) Paved roads are typically swept weekly Reduce Speed 10 mph speed limit signs are posted Reduce Wind Exposure Adjacent buildings/structures/vegetation Weather Natural weather conditions; rain, snow, subfreezing

temperatures 14) FS014/FUGI14: Sodium Bicarbonate Hauling-Paved Roads Material: Road Dusts Additional information:

Trucks deliver sodium bicarbonate by using the main plant paved access road to a storage building located on the south side of the power plant building. The access road is inspected daily for fugitive dust. The road surface is swept at least once per week using a mechanical road sweeper. Summary of Reasonably Available Control Measures: Control Measure Control Action Street Sweeper (seasonal) Paved roads are typically swept weekly Reduce Speed 10 mph speed limit signs are posted Reduce Wind Exposure Adjacent buildings/structures/vegetation





15) FS015/FUGI15: Truck Ash Hauling-Paved Roads Material: Road Dusts Additional information:

Trucks haul ash from the plant on a paved access road located on the south side of the power plant building. The access road is inspected daily for fugitive dust. The road surface is swept at least once per week using a mechanical road sweeper. Summary of Reasonably Available Control Measures: Control Measure Control Action Street Sweeper (seasonal) Paved roads are typically swept weekly Reduce Speed 10 mph speed limit signs are posted Reduce Wind Exposure Adjacent buildings/structures/vegetation Weather Natural weather conditions; rain, snow, subfreezing

temperatures




Figures:

1) Site Map 2) Exhibit A, B, C 3) Process Flow Diagram


Appendix E: Part 63, Subpart UUUUU Equations


Section 63.10009(b) Equations. Use the following equations when performing calculations for your EGU emissions averaging group: (1) Group eligibility equations.

Where: WAERm = Weighted average emissions rate maximum in terms of lb/heat input or lb/gross electrical output, Hermi = Hourly emissions rate (e.g., lb/MMBtu, lb/MWh) from CEMS or sorbent trap monitoring for hour i, Rmmi = Maximum rated heat input or gross electrical output of unit i in terms of heat input or gross electrical output, p = number of EGUs in emissions averaging group that rely on CEMS, n = number of hourly rates collected over 30‐group boiler operating days, Teri = Emissions rate from most recent test of unit i in terms of lb/heat input or lb/gross electrical output, Rmti = Maximum rated heat input or gross electrical output of unit i in terms of lb/heat input or lb/gross electrical output, and m = number of EGUs in emissions averaging group that rely on emissions testing.

Where: variables with similar names share the descriptions for Equation 1a, Smmi = maximum steam generation in units of pounds from unit i that uses CEMS or sorbent trap monitoring, Cfmi = conversion factor, calculated from the most recent emissions test results, in units of heat input per pound of steam generated or gross electrical output per pound of steam generated, from unit i that uses CEMS or sorbent trap monitoring, Smti = maximum steam generation in units of pounds from unit i that uses emissions testing, and Cfti = conversion factor, calculated from the most recent emissions test results, in units of heat input per pound of steam generated or gross electrical output per pound of steam generated, from unit i that uses emissions testing.


(2) Weighted 30‐boiler operating day rolling average emissions rate equations for pollutants other than Hg. Use equation 2a or 2b to calculate the 30‐day rolling average emissions daily.

Where: Heri = hourly emission rate (e.g., lb/MMBtu, lb/MWh) from unit i's CEMS for the preceding 30‐group boiler operating days, Rmi = hourly heat input or gross electrical output from unit i for the preceding 30‐group boiler operating days, p = number of EGUs in emissions averaging group that rely on CEMS or sorbent trap monitoring, n = number of hourly rates collected over 30‐group boiler operating days, Teri = Emissions rate from most recent emissions test of unit i in terms of lb/heat input or lb/gross electrical output, Rti = Total heat input or gross electrical output of unit i for the preceding 30‐boiler operating days, and m = number of EGUs in emissions averaging group that rely on emissions testing.

Where: variables with similar names share the descriptions for Equation 2a, Smi = steam generation in units of pounds from unit i that uses CEMS for the preceding 30‐group boiler operating days, Cfmi = conversion factor, calculated from the most recent compliance test results, in units of heat input per pound of steam generated or gross electrical output per pound of steam generated, from unit i that uses CEMS from the preceding 30 group boiler operating days, Sti = steam generation in units of pounds from unit i that uses emissions testing, and Cfti = conversion factor, calculated from the most recent compliance test results, in units of heat input per pound of steam generated or gross electrical output per pound of steam generated, from unit i that uses emissions testing.


(3) Weighted 90‐boiler operating day rolling average emissions rate equations for Hg emissions from EGUs in the “coal‐fired unit not low rank virgin coal” subcategory. Use equation 3a or 3b to calculate the 90‐day rolling average emissions daily.

Where: Heri = hourly emission rate from unit i's CEMS or Hg sorbent trap monitoring system for the preceding 90‐group boiler operating days, Rmi = hourly heat input or gross electrical output from unit i for the preceding 90‐group boiler operating days, p = number of EGUs in emissions averaging group that rely on CEMS, n = number of hourly rates collected over the 90‐group boiler operating days, Teri = Emissions rate from most recent emissions test of unit i in terms of lb/heat input or lb/gross electrical output, Rti = Total heat input or gross electrical output of unit i for the preceding 90‐boiler operating days, and m = number of EGUs in emissions averaging group that rely on emissions testing.

Where: variables with similar names share the descriptions for Equation 2a, Smi = steam generation in units of pounds from unit i that uses CEMS or a Hg sorbent trap monitoring for the preceding 90‐group boiler operating days, Cfmi = conversion factor, calculated from the most recent compliance test results, in units of heat input per pound of steam generated or gross electrical output per pound of steam generated, from unit i that uses CEMS or sorbent trap monitoring from the preceding 90‐group boiler operating days, Sti = steam generation in units of pounds from unit i that uses emissions testing, and Cfti = conversion factor, calculated from the most recent emissions test results, in units of heat input per pound of steam generated or gross electrical output per pound of steam generated, from unit i that uses emissions testing.


Section 63.10021(b) Equation

Where:

Heri is the hourly emissions rate for hour i and n is the number of hourly emissions rate values collected over 30‐ (or, if applicable, 90‐) boiler operating days.


Appendix F: Consent Decree Definitions


The following is a list of pertinent Consent Decree definitions applicable to the Minnesota Power Taconite Harbor Energy Center. If there is a conflict between the Consent Decree definition of any term below and the Consent Decree for that term, the Consent Decree definition prevails. Refer to the Consent Decree for the definition of any term used in this permit but not defined below. A 12‐Month Rolling Average Emission Rate for a Unit shall be expressed in lb/mmBTU and calculated in accordance with the following procedure: first, sum the total pounds of pollutant emitted from the applicable Unit during the current Operating Month and the previous eleven (11) Operating Months; second, sum the total heat input to the unit in mmBTU during the current Operating Month and the previous eleven (11) Operating Months; and third, divide the total number of pounds of pollutant emitted during the twelve (12) Operating Months by the total heat input during the twelve (12) Operating Months. A new 12‐Month Rolling Average Emission Rate shall be calculated for each new Operating Month in accordance with the provisions of this Consent Decree. Each 12‐Month Rolling Average Emission Rate shall include all emissions of the applicable pollutant that occur during all periods of operation, including startup, shutdown, and Malfunction, except as otherwise provided by Section XV (Force Majeure). A 3‐Hour Rolling Average Emission Rate for a Unit shall be expressed in lb/mmBTU and calculated in accordance with the following procedure: first, sum the total pounds of pollutant emitted from the Unit during the current operating hour and the previous two operating hours; second, sum the total heat input to the Unit in mmBTU during the current operating hour and the previous two operating hours; and third, divide the total number of pounds of pollutant emitted during the three operating hours by the total heat input during the three operating hours. Each 3‐Hour Rolling Average Emission Rate shall include all emissions that occur during all periods within any operating period, including emissions from startup, shutdown, and Malfunction, except as otherwise provided by Section XV (Force Majeure). A 30‐Day Rolling Average Emission Rate for a Unit shall be expressed in lb/mmBTU and calculated in accordance with the following procedure: first, sum the total pounds of pollutant emitted from the applicable Unit during the current Operating Day and the previous twenty‐nine (29) Operating Days; second, sum the total heat input to the unit in mmBTU during the current Operating Day and the previous twenty‐nine (29) Operating Days; and third, divide the total number of pounds of pollutant emitted during the thirty (30) Operating Days by the total heat input during the thirty (30) Operating Days. A new 30‐Day Rolling Average Emission Rate shall be calculated for each new Operating Day. Each 30‐Day Rolling Average Emission Rate shall include all emissions that occur during all periods within any Operating Day, including emissions from startup, shutdown, and Malfunction, except as otherwise provided by Section XV (Force Majeure).

Allowance means an authorization to emit a specified amount of NOx or SO2 that is allocated or issued under an emissions trading or marketable permit program of any kind established under the Clean Air Act or applicable State Implementation Plan; provided, however, that with respect to any such program that first applies to emissions occurring after December 31, 2011, an “Allowance” shall include an Allowance created and allocated to a Minnesota Power System unit under such program only for control periods starting on or after September 29, 2018.

Calendar Year Average Emission Rate for a Unit shall be expressed in lb/mmBTU and calculated by dividing the total number of pounds of pollutant emitted during the calendar year by the total heat input during the calendar year. Each Calendar Year Average Emission Rate shall include all emissions of


the applicable pollutant that occur during all periods of operation, including startup, shutdown, and Malfunction, except as otherwise provided by Section XV (Force Majeure).

Consent Decree means the Consent Decree entered into in United States of America et al v. ALLETE, Inc., d/b/a Minnesota Power, U.S. District Court for the District of Minnesota, Case No.: 0:14‐cv‐2911‐ADM‐LIB, which was signed by the Judge of such Court on September 29, 2014. Continuous Operation and Continuously Operate mean that when a pollution control technology or combustion control is required to be used at a Unit pursuant to this Consent Decree (including, but not limited to a Baghouse, Dry Sorbent Injection system, Electrostatic Precipitator, Flue Gas Desulfurization system, Furnace Sorbent Injection system, Low Nitrogen Oxides Burner, Over Fire Air system, Rotating Opposed Fire Air system, Selective Catalytic Reduction device, Selective Non‐Catalytic Reduction device, Wet Particulate Scrubber, and/or Wet Venturi/ESP device) it shall be operated at all times such Unit is in operation (except as otherwise provided by Section XV Force Majeure), consistent with the technological limitations, manufacturers’ specifications, good engineering and maintenance practices, and good air pollution control practices for minimizing emissions (as defined in 40 C.F.R. § 60.11(d)) for such equipment and the Unit.

Force Majeure. For purposes of this Consent Decree, a “Force Majeure Event” shall mean an event that has been or will be caused by circumstances beyond the control of Minnesota Power, its contractors, or any entity controlled by Minnesota Power that delays or prevents compliance with any provision of this Consent Decree or otherwise causes noncompliance with any provision of this Consent Decree despite Minnesota Power’s best efforts to fulfill the obligation. “Best efforts to fulfill the obligation” include using the best efforts to anticipate any potential Force Majeure Event and to address the effects of any such event (a) as it is occurring, and (b) after it has occurred, such that the delay or noncompliance, and any adverse environmental effect of the delay or noncompliance, is minimized to the greatest extent possible. Fossil Fuel means any hydrocarbon fuel, including coal, petroleum coke, petroleum oil, fuel oil, or natural gas. Malfunction means any sudden, infrequent, and not reasonably preventable failure of air pollution control equipment, process equipment, or a process to operate in a normal or usual manner. Failures that are caused in part by poor maintenance or careless operation are not Malfunctions. Minnesota Power System means, solely for purposes of this Consent Decree, Minnesota Power’s Boswell Energy Center Units 1 through 4, Laskin Energy Center Units 1 and 2, Taconite Harbor Energy Center Units 1 through 3, and Rapids Energy Center Units 5 and 6. National Ambient Air Quality Standards or NAAQS means national ambient air quality standards promulgated pursuant to Section 109 of the Act, 42 U.S.C. § 7409. Natural Gas means natural gas received directly or indirectly through a connection to an interstate pipeline.


Netting shall mean the process of determining whether a particular physical change or change in the method of operation of a major stationary source results in a net emissions increase, as that term is defined at 40 C.F.R. § 52.21(b)(3)(i), and/or an applicable State Implementation Plan (“SIP”) and/or other clean air rules administered by MPCA. NOx Allowance means an authorization to emit a specified amount of NOx that is allocated or issued under an emissions trading or marketable permit program of any kind established under the Clean Air Act or applicable State Implementation Plan; provided, however, that with respect to any such program that first applies to emissions occurring after December 31, 2011, a “NOx Allowance” shall include a NOx Allowance created and allocated to a Minnesota Power System Unit under such program only for control periods starting on or after the fourth anniversary of the Date of Entry of this Consent Decree. Nonattainment NSR means the new source review program within the meaning of Part D of Title I of the Act, 42 U.S.C. §§ 7501‐7515 and 40 C.F.R. Part 51, and corresponding provisions of an applicable SIP, and all rules addressing nonattainment new source review administered by MPCA. Operating Day means any calendar Day on which a Unit fires Fossil Fuel. Operating Month means any calendar month during which a Unit fires Fossil Fuel. Particulate Matter Control Device or PM Control Device means any device including a Baghouse, ESP, or Wet Particulate Scrubber which reduces emissions of PM. Prevention of Significant Deterioration or PSD means the new source review program within the meaning of Part C of Title I of the Clean Air Act, 42 U.S.C. §§ 7470‐7492 and 40 C.F.R. Part 52, and Minn. R., Chapter 7007 (Permits and Offsets). Refuel or Refueled means the alteration of a Unit such that the altered Unit can no longer combust any fuel (such as coal, petroleum coke, petroleum oil, fuel oil) except Natural Gas, and/or herbaceous crops, trees, agricultural waste, logging or silvicultural waste, untreated wood residue or products, aquatic plant matter or other non‐Fossil Fuel approved by EPA and MPCA. Repower or Repowered means, solely for purposes of this Consent Decree replacement of the Unit components such that the Unit is solely able to generate electricity through the use of a combined cycle combustion turbine technology from the combustion of Natural Gas rather than coal or another Fossil Fuel (such as coal, petroleum coke, petroleum oil, fuel oil). Retire means to permanently shut down a Unit and to comply with applicable state and federal requirements for permanently ceasing operation of the Unit, including submitting a request to MPCA to amend the state’s air emission inventory to reflect shutdown, and withdrawing and/or requesting amendment of all applicable permits so as to reflect the permanent shutdown status of such Unit. Super‐Compliant Allowance means a NOx Allowance or SO2 Allowance attributable to reductions beyond the requirements of this Consent Decree, as described in Paragraphs 96 and 117. Surrender or Surrender of Allowances means, for purposes of SO2 Allowances or NOx Allowances, permanently surrendering SO2 Allowances or NOx Allowances from the accounts administered by EPA


and MPCA for all Units in the Minnesota Power System, so that such SO2 Allowances or NOx Allowances can never be used thereafter to meet any compliance requirements under the Clean Air Act, or this Consent Decree. System‐Wide Annual Tonnage Limitation means the limitation, as specified in this Consent Decree, on the number of tons of pollutant (SO2 or NOx) that may be emitted from the Boswell, Taconite Harbor, Laskin, and Rapids Energy Centers during the relevant calendar year (i.e., January 1 through December 31), and shall include all emissions of the specified pollutant that occur during all periods of operation, including startup, shutdown, and Malfunction.


Appendix G: Transport Rule Requirements


Transport Rule (TR) Trading Program Title V Requirements Description of TR Monitoring Provisions The TR subject unit(s), and the unit-specific monitoring provisions at this source, are identified in the following tables. These units are subject to the requirements for the TR NOX Annual Trading Program and the TR SO2 Group 2 Trading Program.

Unit ID: Boiler 1 (EU 001/EQUI64) Coal-Fired steam-electric utility boiler Continuous

emission monitoring system or systems (CEMS) Requirements pursuant to 40 CFR part 75, subpart B (for SO2 monitoring) and 40 CFR part 75, subpart H (for NOX

monitoring)

Excepted monitoring system requirements for gas- and oil-fired units pursuant to 40 CFR part 75, appendix D

Excepted monitoring system requirements for gas- and oil-fired peaking units pursuant to 40 CFR part 75, appendix E

Low Mass Emissions e xcepted monitoring (LME) requirements for gas- and oil-fired units pursuant to 40 CFR 75.19

EPA-approved alternative monitoring system requirements pursuant to 40 CFR part 75, subpart E

SO2 X ----------------

NOX X -------------

Heat input X ----------------

1. The above description of the monitoring used by a unit does not change, create an exemption from, or otherwise affect the monitoring, recordkeeping, and reporting requirements applicable to the unit under 40 CFR 97.430 through 97.435 and 40 CFR 97.730 through 97.735. The monitoring, recordkeeping and reporting requirements applicable to each unit are included below in the standard conditions for the applicable TR trading programs.

2. Owners and operators must submit to the Administrator a monitoring plan for each unit in accordance with 40 CFR 75.53, 75.62 and 75.73, as applicable. The monitoring plan for each unit is available at the EPA’s website at http://www.epa.gov/airmarkets/emissions/monitoringplans.html.

3. Owners and operators that want to use an alternative monitoring system must submit to the Administrator a petition requesting approval of the alternative monitoring system in accordance with 40 CFR part 75, subpart E and 40 CFR 75.66 and 97.435 and 97.735. The Administrator’s response approving or disapproving any petition for an alternative monitoring system is available on the EPA’s website at http://www.epa.gov/airmarkets/emissions/petitions.html.


4. Owners and operators that want to use an alternative to any monitoring, recordkeeping, or reporting requirement under 40 CFR 97.430 through 97.434 and 97.730 through 97.734, must submit to the Administrator a petition requesting approval of the alternative in accordance with 40 CFR 75.66, and 40 CFR 97.435 and 97.735. The Administrator’s response approving or disapproving any petition for an alternative to a monitoring, recordkeeping, or reporting requirement is available on EPA’s website at http://www.epa.gov/airmarkets/emissions/petitions.html.

5. The descriptions of monitoring applicable to the unit included above meet the requirement of 40 CFR 97.430 through 97.434 and 97.730 through 97.734 and therefore minor permit modification procedures, in accordance with 40 CFR 70.7(e)(2)(i)(B) or 71.7(e)(1)(i)(B), may be used to add to or change this unit’s monitoring system description.


Transport Rule (TR) Trading Program Title V Requirements Description of TR Monitoring Provisions The TR subject unit(s), and the unit-specific monitoring provisions at this source, are identified in the following tables. These units are subject to the requirements for the TR NOX Annual Trading Program and the TR SO2 Group 2 Trading Program.

Unit ID: Boiler 2 (EU 002/EQUI5) Coal-Fired steam-electric utility boiler Continuous

emission monitoring system or systems (CEMS) Requirements pursuant to 40 CFR part 75, subpart B (for SO2 monitoring) and 40 CFR part 75, subpart H (for NOX

monitoring)

Excepted monitoring system requirements for gas- and oil-fired units pursuant to 40 CFR part 75, appendix D

Excepted monitoring system requirements for gas- and oil-fired peaking units pursuant to 40 CFR part 75, appendix E

Low Mass Emissions e xcepted monitoring (LME) requirements for gas- and oil-fired units pursuant to 40 CFR 75.19

EPA-approved alternative monitoring system requirements pursuant to 40 CFR part 75, subpart E

SO2 X ----------------

NOX X -------------

Heat input X ----------------

1. The above description of the monitoring used by a unit does not change, create an exemption from, or otherwise affect the monitoring, recordkeeping, and reporting requirements applicable to the unit under 40 CFR 97.430 through 97.435 and 40 CFR 97.730 through 97.735. The monitoring, recordkeeping and reporting requirements applicable to each unit are included below in the standard conditions for the applicable TR trading programs.

2. Owners and operators must submit to the Administrator a monitoring plan for each unit in accordance with 40 CFR 75.53, 75.62 and 75.73, as applicable. The monitoring plan for each unit is available at the EPA’s website at http://www.epa.gov/airmarkets/emissions/monitoringplans.html.

3. Owners and operators that want to use an alternative monitoring system must submit to the Administrator a petition requesting approval of the alternative monitoring system in accordance with 40 CFR part 75, subpart E and 40 CFR 75.66 and 97.435 and 97.735. The Administrator’s response approving or disapproving any petition for an alternative monitoring system is available on the EPA’s website at http://www.epa.gov/airmarkets/emissions/petitions.html.


4. Owners and operators that want to use an alternative to any monitoring, recordkeeping, or reporting requirement under 40 CFR 97.430 through 97.434 and 97.730 through 97.734, must submit to the Administrator a petition requesting approval of the alternative in accordance with 40 CFR 75.66, and 40 CFR 97.435 and 97.735. The Administrator’s response approving or disapproving any petition for an alternative to a monitoring, recordkeeping, or reporting requirement is available on EPA’s website at http://www.epa.gov/airmarkets/emissions/petitions.html.

5. The descriptions of monitoring applicable to the unit included above meet the requirement of 40 CFR 97.430 through 97.434 and 97.730 through 97.734 and therefore minor permit modification procedures, in accordance with 40 CFR 70.7(e)(2)(i)(B) or 71.7(e)(1)(i)(B), may be used to add to or change this unit’s monitoring system description.

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