Calpine Corporation (owner) Calpine Operating Services ...

Draft Air Individual Permit Major Amendment

01300098-101

Permittee: Mankato Energy Center, LLC/Mankato Energy Center II, LLC (owners) Calpine Corporation (owner) Calpine Operating Services Company, Inc. (operator)

Facility name: Mankato Energy Center 1 Fazio Lane Mankato, MN 56001 Blue Earth County

Operating permit issuance date: February 14, 2014

Expiration date: February 14, 2019 * All Title I Conditions do not expire

Major Amendment: [Amendment Issue Date]

Permit characteristics: Federal; Part 70/ Major for NSR; NSR Authorization

*The Permittee may continue to operate this facility after the expiration date of the permit, per the provision underMinn. R. 7007.0450, subp. 3.

The emission units, control equipment and emission stacks at the stationary source authorized in this permit amendment are as described in the Permit Applications Table.

This permit amendment supersedes Air Emission Permit No. 01300098-002 and authorizes the Permittee to operate and construct 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 as defined in the state air pollution control rules unless the term is explicitly defined in the permit.

Unless otherwise indicated, all the Minnesota rules cited as the origin of the permit terms are incorporated into the 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 Don Smith, P.E., Manager Air Quality Permits 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 .................................................................................................................................... 9 6. Submittal/action requirements ............................................................................................................................... 121 7. Appendices ............................................................................................................................................................... 132

Appendix A. Insignificant Activities and General Applicable Requirements .......................................................... 132 Appendix B: Modeling Parameters ........................................................................................................................ 133 Appendix C: Acid Rain Permit Application ............................................................................................................. 134 Appendix D: Transport Rule (TR) Trading Program Title V Requirements ............................................................. 139

Permit issued: [month day, year] 01300098-101 Permit expires: [month day, year] of 141

1. Permit applications table Subsequent permit applications: Title description Application receipt date Action number Part 70 Reissuance 03/17/2009 01300098-002 Major Amendment 11/03/2015 01300098-101


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 The Mankato Energy Center (Facility) is located at 1 Fazio Lane in Mankato, Blue Earth County, Minnesota. Mankato Energy Center is an electric generating plant owned by Mankato Energy Center, LLC and Mankato Energy Center II, LLC. The Facility is capable of producing 720 megawatts of electricity at peak load at winter conditions using twin combined cycle gas turbine generators fired primarily by natural gas. CT #2 has the capability to also fire fuel oil. Each gas turbine is equipped with a heat recovery steam generator and duct burners to supply steam to a common steam turbine electric generator. The Facility also includes an auxiliary boiler, emergency generator, fire pump engine, fuel oil storage tanks and a cooling tower. The Facility is a major source under the Part 70 permit program and federal New Source Review/Prevention of Significant Deterioration program. The Facility has accepted federally enforceable conditions limiting the amount of Hazardous Air Pollutant emissions, such that it is classified as an area source under the National Emissions Standards for Hazardous Air Pollutants for individual source categories (40 CFR pt. 63). Permit Action 101 description: Mankato Energy Center II, LLC proposes to install a new combustion turbine/HRSG train converting the existing facility to a 2X1 combined cycle unit. The new combustion turbine (CT)/HRSG train will be owned by Mankato Energy Center II, LLC (MEC II) and operated by Calpine Operating Services Company, Inc. It will generate an additional 345 MW at peak load at winter ambient conditions. The CT will be fired by natural gas only and exhaust to a separate HRSG having a supplementary duct firing capacity of 824 mmBtu/hr. The duct burners will be fired with natural gas. Steam generated by the new HRSG will exhaust to the existing steam turbine. MEC II will install SCR and DLN burners to reduce NOx emissions and a catalyst oxidation system to control CO and VOC emissions. The HRSG low-NOx duct burner will be controlled by the SCR and oxidation catalyst. To provide additional cooling due to increased steam flow to the steam turbine, four new cells will be added to the existing cooling tower. The Facility also is adding a diesel fired emergency generator.


4. Summary of subject items

SI ID: Description

Relationship Type

Related SI ID: Description

ACTV3: All IAs

COMG5: Formaldehyde, n-Hexane, and Total HAPs

has members

EQUI5, EQUI6, EQUI7, EQUI11, EQUI16, EQUI17, EQUI18, EQUI19, STRU14, STRU17, STRU18, STRU20, STRU21, STRU22, TREA4, TREA5, TREA6, TREA9, TREA11, TREA12

COMG6: Combustion Turbines and Duct Burners (SV002 & SV007)

has members

EQUI5, EQUI6, EQUI16, EQUI17, STRU14, STRU20, TREA4, TREA5, TREA6, TREA9, TREA11, TREA12

EQUI11: Fire Pump Engine

sends to STRU18: Fire Pump Engine Stack

EQUI16: Combustion Turbine #1

sends to EQUI20: CT #1 CEMS


is monitored by

EQUI21: NOx CEM for CT #1


is monitored by

EQUI22: CO CEM for CT #1


sends to STRU20: Combustion Turbine #1 & Duct Burners #1 Stack


is controlled by

TREA11: SCR (Selective Catalytic

SI ID: Description

Relationship Type


Reduction) for CT #1


is controlled by

TREA12: Catalytic Oxidizer for CT #1

EQUI17: Duct Burners (Combustion Turbine #1)



is controlled by

TREA11: SCR (Selective Catalytic Reduction) for CT #1


is controlled by


EQUI18: Diesel Fired Emergency Generator

sends to STRU21: Diesel Fired Emergency Generator Stack

EQUI19: Bath Heater

sends to STRU22: Bath Heater Stack

EQUI20: CT #1 CEMS





EQUI23: Diesel Fired Emergency Generator Tank

EQUI24: Natural Gas Condensate Tank - Plant

EQUI2: CT #2 CEMS







Permit Issued: [month day, year] 01300098-101 Permit Expires: [month day, year] of 141

SI ID: Description

Relationship Type



is monitored by



is monitored by





is controlled by

TREA4: Steam or Water Injection for CT #2


is controlled by



is controlled by



is controlled by

TREA9: Lean Pre-mix DLN Combustion for CT #2

EQUI6: Duct Burner (Combustion Turbine #2)



is controlled by



is controlled by


EQUI7: Auxiliary Boiler

sends to STRU17: Auxiliary Boiler Stack

EQUI7: Auxiliary Boiler

is controlled by

TREA7: Low NOx Burners for EQUI 7

FUGI1: Cooling Tower

SI ID: Description

Relationship Type


FUGI2: Natural Gas Fugitives

FUGI3: Breaker Fugitives

STRU10: Demineralized Water Storage Tank (SPF: 24)

STRU11: Fuel Oil Storage Tank (Site Plan Reference: 58)

STRU12: Raw Water Storage Tank (Site Plan Refere:23)

STRU13: Existing Warehouse Building (Site Plan Ref:15)

STRU14: Combustion Turbine #2 & Duct Burners #2 Stack

STRU17: Auxiliary Boiler Stack

STRU18: Fire Pump Engine Stack

STRU1: Administration / Warehouse Building (SPF: 14)

STRU20: Combustion Turbine #1 & Duct Burners #1 Stack

STRU21: Diesel Fired Emergency Generator Stack

STRU22: Bath Heater Stack

STRU2: Water Treatment/ Electrical Control Building(13)

STRU3: Fire Pump House (Site Plan Reference: 52)

STRU4: Cooling Tower (Site Plan Reference: 20)


SI ID: Description

Relationship Type


STRU5: Cooling Tower Chemical Feed Building (28)

STRU6: Heat Recovery Steam Generator #2 (SPF: 4)

STRU7: Steam Turbine Generator Building (SPF: 56)

STRU8: Combustion Turbine #2 (Site Plan Reference:2)

STRU9: Auxiliary Boiler (Site Plan Reference: 53)

TFAC1: Mankato Energy Center LLC



is controlled in series by

TREA11: SCR (Selective Catalytic

SI ID: Description

Relationship Type

Related SI ID: Description Reduction) for CT #1




TREA7: Low NOx Burners for EQUI 7











5. Limits and other requirements Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation TFAC 1 01300098 Mankato Energy

Center LLC

5.1.1 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 (Insignificant Activities and Applicable Requirements); C (Acid Rain Permit Application); and D (Transport Rule (TR) Trading Program Title V Requirements). Modeling parameters in Appendix B (Stack Parameters Relied Upon in Modeling) are included for reference only as described elsewhere in this permit. [Minn. R. 7007.0800, subp. 2]

5.1.2 The Permittee is authorized to construct EQUI 16 (approximately 200 MW Combustion Turbine #1 with dry low NOx burners at 6 degrees F), EQUI 17 (824 mmBtu/hr Duct Burners), EQUI 18 (2500 kW Diesel Fired Emergency Generator), EQUI 20 (CT#1 CEMS Data Acquisition System), EQUI 21 (CT#1 NOx CEMS), EQUI 22 (CT#1 CO CEMS), TREA 11 (Selective Catalytic Reduction), TREA 12 (Catalytic Oxidizer), FUGI 2 (Natural Gas Fugitives), FUGI 3 (Breaker Fugitives), additional 4 cells to FUGI 1 (Cooling Tower). The construction authorization expires if construction does not commence within 18 months after receipt of such approval by Air Emissions Permit No. 01300098-101, if construction is discontinued for a period of 18 months or more, or if construction is not completed within a reasonable time. [40 CFR 52.21(r)(2) & Minn. R. 7007.3000]

5.1.3 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)]

5.1.4 Modeled Parameters for CO: The parameters used in CO modeling for permit number 01300098-002 are listed in Appendix B 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. 7007.3000, Title I Condition: 40 CFR 52.21(k)]


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

5.1.5 Changes to Modeled Parameters for CO: Any permit amendment that affects any modeled parameter or emission rate for CO listed in Appendix B must be a major amendment. Any addition to the information documented in Appendix B requires a major amendment. [Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)]

5.1.6 Equivalent or Better Dispersion (EBD) Modeling Triggers (Modeling Required) for NOx: Changes that affect any modeled parameter or emission rate listed in Appendix B, or an addition to the information documented in Appendix B, trigger the EBD Modeling Submittal requirement. [Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)]

5.1.7 EBD Modeling Submittal Content for NOx: The information submitted must include, for stack and vent sources, source emission rate, location, height, diameters, exit velocity, exit temperature, discharge direction, use of rain caps or rain hats, and, if applicable, locations and dimensions of nearby buildings. For non-stack/vent sources, this includes the source emission rate, location, size and shape, release height, and, if applicable, any emission rate scalars, and the initial lateral dimensions and initial vertical dimensions and adjacent building heights. [Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)]

5.1.8 EBD Modeling Submittal for NOx: For changes meeting the criteria in the EBD Modeling Triggers (Modeling Required) requirement, the Permittee shall submit an EBD modeling submittal in accordance with the current version of the MPCA Air Dispersion Modeling Guidance at the time of the modeling and shall wait for written approval (in the form of an issued permit amendment) before making such changes. [Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)]

5.1.9 Outdated EBD Baseline Modeling for NOx: Prior to conducting the EBD analysis, the Permittee shall use the current version of the MPCA Air Dispersion Modeling Guidance to determine if the Baseline Modeling (the most recent refined modeling demonstration) is outdated. If the Baseline Modeling is outdated, the Permittee shall update the Baseline Modeling to be consistent with the current version of the MPCA Air Dispersion Modeling Guidance. The updated modeling will become the new Baseline Modeling. This requirement does not require the Permittee to complete a new refined modeling demonstration using the revisions made for the EBD demonstration. [Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)]

5.1.10 EBD Modeling Results for NOx: The dispersion characteristics due to the revisions of the information in Appendix B must be equivalent to or better than the dispersion characteristics modeled October 2015. The Permittee shall demonstrate this equivalency in the proposal. [Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)]

5.1.11 Computer Dispersion Modeling Triggers for NOx: The



Permittee shall conduct a refined remodeling analysis in accordance with the Computer Dispersion Modeling requirements of this permit and the current version of the MPCA Air Dispersion Modeling Guidance if: (1) the results of the EBD modeling analysis do not demonstrate equivalent or better dispersion characteristics; (2) a conclusion cannot readily be made about the dispersion, or (3) the criteria in the EBD Modeling Triggers requirement are met and the Permittee has previously conducted three successive EBD analyses using the same Baseline Modeling. [Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)]

5.1.12 Computer Dispersion Modeling Protocol: due 180 days after receipt of written MPCA request for NOx refined modeling. The Permittee shall submit a Computer Dispersion Modeling Protocol that is complete and approvable by MPCA by the deadline in this requirement. This protocol will describe the proposed modeling methodology and input data, in accordance with the current version of the MPCA Air Dispersion Modeling Guidance. The protocol must be based on projected operating conditions under the next permit term. [Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)]

5.1.13 Computer Dispersion Modeling Protocol: due 60 days after receipt of written MPCA request for revisions to the submitted protocol for NOx modeling. [Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)]

5.1.14 Computer Dispersion Modeling Results: due 180 days after receipt of written MPCA approval of Computer Dispersion Modeling Protocol for NOx. The Permittee shall submit a final Computer Dispersion Modeling Report that is complete and approvable by MPCA by the deadline in this requirement. The submittal shall adhere to the current version of the MPCA Air Dispersion Modeling Guidance and the approved Computer Dispersion Modeling Protocol. [Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)]

5.1.15 This source is subject to the U.S. EPA Acid Rain Program codified at 40 CFR pts. 72, 73, and 75. Each combustion turbine and duct burner (EQUI 5/EQUI 6 and EQUI 16/EQUI 17) is a utility unit that also is a gas-fired unit and a new unit, as defined in 40 CFR Section 72.2. Some of the Acid Rain Program requirements are included in this permit for MPCA tracking purposes. The Permittee's acid rain permit application is in Appendix C of this permit. [40 CFR pt. 72, 40 CFR pt. 73, 40 CFR pt. 75, Minn. R. 7007.1075]

5.1.16 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, recordkeeping, or notification may still be required by Minn. R. 7007.1150 - 7007.1500. [Minn. R. 7007.0800, subp. 2, Title I Condition: 40 CFR 52.21(r)(6) and Minn. R. 7007.3000]

5.1.17 Preconstruction Documentation -- Before beginning actual construction on a project, the Permittee shall document the following: 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) and Minn. R. 7007.3000]

5.1.18 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) and Minn. R. 7007.3000]

5.1.19 The Permittee must submit a report to the Agency if the annual summed (actual, plus potential if 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 increase are 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) and Minn. R. 7007.3000]

5.1.20 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)(ii) and Minn. R. 7007.3000]

5.1.21 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) and Minn. R. 7007.3000]

5.1.22 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) and Minn. R. 7007.3000]

5.1.23 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. [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]

5.1.24 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]

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

5.1.26 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)]

5.1.27 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]

5.1.28 Fugitive Emissions: Do not cause or permit the handling, use, transporting, or storage of any material in a manner which may allow avoidable amounts of particulate matter to become airborne. Comply with all other requirements listed in Minn. R. 7011.0150. [Minn. R. 7011.0150]

5.1.29 Noise: The Permittee shall comply with the noise standards set forth in Minn. R. 7030.0010 to 7030.0080 at all times during the operation of any emission units. This is a state only requirement and is not enforceable by the EPA Administrator or citizens under the Clean Air Act. [Minn. R. 7030.0010-7030.0080]



5.1.30 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)]

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

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

5.1.33 Performance Test Notifications and Submittals: Performance Tests are due as outlined in this permit. Performance Test Notification (written): due 30 days before each Performance Test Performance Test Plan: due 30 days before each Performance Test Performance Test Pre-test Meeting: due 7 days before each Performance Test Performance Test Report: due 45 days after each Performance Test Performance Test Report - Microfiche Copy: due 105 days after each Performance Test The Notification, Test Plan, and Test Report may be submitted in an alternative format as allowed by Minn. R. 7017.2018. [Minn. R. 7017.2018, Minn. R. 7017.2030, subps. 1-4, Minn. R. 7017.2035, subps. 1-2]

5.1.34 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]

5.1.35 Monitoring Equipment Calibration - The Permittee shall either: 1. Calibrate or replace required monitoring equipment every 12 months; or 2. Calibrate at the frequency stated in the manufacturer's specifications. For each monitor, the Permittee shall maintain a record of all calibrations, including the date conducted, and any corrective action that resulted. The Permittee shall include the calibration frequencies, procedures, and manufacturer's specifications (if applicable) in the Operations and Maintenance Plan. Any requirements applying to continuous emission monitors are listed separately in this permit. [Minn. R. 7007.0800, subp. 4(D)]

5.1.36 Operation of Monitoring Equipment: Unless noted elsewhere in this permit, monitoring a process or control equipment connected to that process is not necessary during periods



when the process is shutdown, or during checks of the monitoring systems, such as calibration checks and zero and span adjustments. If monitoring records are required, they should reflect any such periods of process shutdown or checks of the monitoring system. [Minn. R. 7007.0800, subp. 4(D)]

5.1.37 Recordkeeping: Retain all records at the stationary source, unless otherwise specified within this permit, for a period of five (5) years from the date of monitoring, sample, measurement, or report. Records which must be retained at this location include all calibration and maintenance records, all original recordings for continuous monitoring instrumentation, and copies of all reports required by the permit. Records must conform to the requirements listed in Minn. R. 7007.0800, subp. 5(A). [Minn. R. 7007.0800, subp. 5(C)]

5.1.38 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)]

5.1.39 If the Permittee determines that no permit amendment or notification is required prior to making a change, the Permittee must retain records of all calculations required under Minn. R. 7007.1200. For expiring permits, these records shall be kept for a period of five years from the date the change was made or until permit reissuance, whichever is longer. The records shall be kept at the stationary source for the current calendar year of operation and may be kept at the stationary source or office of the stationary source for all other years. The records may be maintained in either electronic or paper format. [Minn. R. 7007.1200, subp. 4]

5.1.40 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]

5.1.41 Breakdown Notifications: Notify the Commissioner within 24 hours of a breakdown of more than one hour duration of any control equipment or process equipment if the breakdown causes any increase in the emissions of any regulated air pollutant. The 24-hour time period starts when the breakdown was discovered or reasonably should have been discovered by



the owner or operator. However, notification is not required in the circumstances outlined in Items A, B and C of Minn. R. 7019.1000, subp. 2. At the time of notification or as soon as possible thereafter, the owner or operator shall inform the Commissioner of the cause of the breakdown and the estimated duration. The owner or operator shall notify the Commissioner when the breakdown is over. [Minn. R. 7019.1000, subp. 2]

5.1.42 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]

5.1.43 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]

5.1.44 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. [Minn. R. 7007.0400, subp. 3, Minn. R. 7007.1150 - 7007.1500]

5.1.45 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 do not meet the requirements of Minn. R. 7007.1400, subp. 1(H). [Minn. R. 7007.1400, subp. 1(H)]



5.1.46 Emission Inventory Report: due on or before April 1 of each calendar year following permit issuance, to be submitted on a form approved by the Commissioner. [Minn. R. 7019.3000-7019.3100]

5.1.47 Emission Fees: due 30 days after receipt of an MPCA bill. [Minn. R. 7002.0005-7002.0095]

COMG 5 Formaldehyde, n-Hexane, and Total HAPs

5.2.1 Formaldehyde <= 9.0 tons per year 12-month rolling sum, regardless of fuel type. This limit applies to the total combined emissions from the subject items associated with COMG 5, and at all times including startup, shutdown, and malfunction. [Minn. R. 7011.7000, Title I Condition: Avoid major source under 40 CFR 63.2]

5.2.2 Hexane <= 9.0 tons per year 12-month rolling sum, regardless of fuel type. This limit applies to the total combined emissions from the subject items associated with COMG 5, and at all times including startup, shutdown, and malfunction. [Minn. R. 7011.7000, Title I Condition: Avoid major source under 40 CFR 63.2]

5.2.3 HAPs - Total <= 22.5 tons per year 12-month rolling sum. This limit applies to the total combined emissions from the subject items associated with COMG 5, and at all times including startup, shutdown, and malfunction. [Minn. R. 7011.7000, Title I Condition: Avoid major source under 40 CFR 63.2]

5.2.4 HAP Emissions Monitoring: The Permittee shall determine EQUI 7, EQUI 11, EQUI 18 and EQUI 19 formaldehyde, n-hexane, other single HAPs, and total HAP emissions using monthly heat input records, monthly operating hours, and applicable emission factors as listed below. EQUI 7: AP 42 Tables 1.4-3 and 1.4-4; EQUI 11: AP 42 Table 3.3-2; EQUI 18: AP 42 Tables 3.3-2, 3.4-3 and 3.4-4; EQUI 19: AP 42 Tables 1.4-3 and 1.4-4. [Minn. R. 7007.0800, subp. 4, Minn. R. 7011.7000, Title I Condition: Avoid major source under 40 CFR 63.2]

5.2.5 Monthly Heat Input Monitoring: By the 15th of the month, the Permittee shall calculate and record total heat input (in million Btus) for EQUI 7, EQUI 11, EQUI 18 and EQUI 19 for the previous operating month. [Minn. R. 7007.0800, subp. 4, Minn. R. 7011.7000, Title I Condition: Avoid major source under 40 CFR 63.2]

5.2.6 Monthly HAPs Emissions Monitoring and Recordkeeping: By the 15th of the month, the Permittee shall calculate and record monthly EQUI 7, EQUI 11, EQUI 18 and EQUI 19 formaldehyde, n-hexane and total HAP emissions for the previous calendar month, and the 12 month rolling sum by summing the formaldehyde, n-hexane and total HAP emissions for the previous 12 months. Formaldehyde, n-hexane and other single HAP emissions are



determined using monthly EQUI 7, EQUI 11, EQUI 18 and EQUI 19 heat input data and the applicable lb/mmBtu emission factor from the appropriate Table in AP 42. Total HAP emissions are determined by summing all individual HAPs data for the previous calendar month and previous 12 months (12-month rolling sum). [Minn. R. 7007.0800, subps. 4-5, Minn. R. 7011.7000, Title I Condition: Avoid major source under 40 CFR 63.2]

5.2.7 HAP Emissions Monitoring, Daily Heat Input Monitoring and Monthly HAPs Emissions Monitoring and Recordkeeping requirements are located at STRU 14 for EQUI 5 and EQUI 6, and at STRU 20 for EQUI 16 and EQUI 17. [Minn. R. 7007.0800, subp. 2]

5.2.8 In lieu of using monthly recordkeeping for EQUI 7, EQUI 11, EQUI 18 and EQUI 19, the Permittee may use the following monthly potential to emit values: EQUI 7: Formaldehyde = 0.002 tons/month, n-hexane = 0.045 tons/month, Total HAPs = 0.048 tons/month EQUI 11: Formaldehyde = 1.2E-05 tons/month, n-hexane = 0 tons/month, Total HAPs = 3.95E-05 tons/month EQUI 18: Formaldehyde = 8.36E-06 tons/month, n-hexane = 0 tons/month, Total HAPs = 1.71E-04 tons/month EQUI 19: Formaldehyde = 7.70E-05 tons/month, n-hexane = 1.85E-03 tons/month, Total HAPs = 1.94E-03 tons/month. [Minn. R. 7007.0800, subps. 4-5, Minn. R. 7011.7000, Title I Condition: Avoid major source under 40 CFR 63.2]

EQUI 3 MR003 NOx CEM for CT #2

5.3.1 NOx CEMS Daily Calibration Error (CE) Test: Conduct daily CE testing on the NOx CEMS in accordance with 40 CFR pt. 75, Appendix B. [40 CFR pt. 75, Appendix B(Sect 2.1)]

5.3.2 NOx CEMS RATA Notification: due 30 days before CEMS Relative Accuracy Test Audit (RATA). [Minn. R. 7017.1180, subp. 2]

5.3.3 NOx CEMS Relative Accuracy Test Audit (RATA): Due semiannually following Permit Issuance, i.e., once every two successive QA operating quarters (calendar quarter in which there are at least 168 unit operating hours). Conduct a RATA on all CEMS required by the Acid Rain Program, in accordance with 40 CFR pt. 75, Appendix B. Relative accuracy test audits may be performed annually (i.e., once every four successive QA operating quarters, rather than once every two successive QA operating quarters) if any of the conditions listed in 40 CFR pt. 75, Appendix B, Sections 2.3.1.2(a) through 2.3.1.2(i) are met. [40 CFR pt. 75, Appendix B (Sect 2.3.1), Minn. R. 7017.1020]

5.3.4 Relative Accuracy Test Audit (RATA) Results Summary: due 30 days after end of each calendar quarter in which a RATA was conducted. [Minn. R. 7017.1180, subp. 3]

5.3.5 Cylinder Gas Audit (CGA) Results Summary: due 30 days after end of each calendar quarter in which a CGA was conducted.



[Minn. R. 7017.1180, subp. 1]

5.3.6 The CEMS/COMS requirements listed below outline the typical standards of 40 CFR Pt. 75. Additional monitoring requirements may also apply to the Facility based on the standard and it is the responsibility of the Facility to meet all applicable requirements. [Minn. R. 7007.subp. 4, A]

5.3.7 Emissions Monitoring: The owner or operator shall use a CEMS to measure emissions from EQUI 5. [40 CFR 75.10(a)]

5.3.8 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 owner or operator 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)]

5.3.9 CEMS QA/QC NOx and Diluent Monitoring: The owner or operator of an affected facility shall operate, calibrate, and maintain each CEMS according to the QA/QC procedures in 40 CFR pt. 75, Appendix B as amended. [40 CFR 75.21(a)]

5.3.10 Quarterly Reports: Electronically report the data and information in 40 CFR Section 75.64 (a), (b), and (c) to the Administrator quarterly. [40 CFR 75.64]

5.3.11 Recordkeeping: The owner or operator shall maintain for each affected unit a file of all measurements, data, reports, and other information required by this part 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]

EQUI 4 MR004 CO CEM for CT #2

5.4.1 CEMS QA/QC Diluent Monitoring: The owner or operator of an affected facility shall operate, calibrate, and maintain each CEMS according to the QA/QC procedures in 40 CFR pt. 75, Appendix B as amended. [40 CFR 75.21(a)]

5.4.2 Relative Accuracy Test Audit (RATA) Notification: due 30 days before CO CEMS Relative Accuracy Test Audit (RATA). [Minn. R. 7017.1180, subp. 2]


5.4.4 Cylinder Gas Audit (CGA) Results Summary: due 30 days after end of each calendar quarter in which a CGA was conducted.



[Minn. R. 7017.1180, subp. 1]

5.4.5 The CEMS/COMS requirements listed below outline the typical standards of 40 CFR pt. 60 when combined with Minn. R. Additional monitoring requirements may also apply to the Facility based on this combination of standards and it is the responsibility of the Facility to meet all applicable requirements. [Minn. R. 7017.1010]

5.4.6 Carbon Monoxide: Emissions Monitoring: The owner or operator shall use a CEMS to measure emissions from EQUI 5. [40 CFR pt. 60, subp. GG, Minn. R. 7017.1010, subp 1]

5.4.7 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. [40 CFR 60.7(a)(5), Minn. R. 7017.1060, subp. 1-3, Minn. R. 7017.1080, subp. 1-4]

5.4.8 Continuous Operation: CEMS must be operated and data recorded during all periods of emission unit operation including periods of emission unit start-up, shutdown, or malfunction except for periods of acceptable monitor downtime. This requirement applies whether or not a numerical emission limit applies during these periods. A CEMS must not be bypassed except in emergencies where failure to bypass would endanger human health, safety, or plant equipment. [40 CFR 60.13(e), Minn. R. 7017.1090]

5.4.9 QA Plan: Develop and implement a written quality assurance plan that covers each CEMS. The plan shall be on site and available for inspection within 30 days after monitor certification. The plan shall contain all of the information required by 40 CFR Part 60, Appendix F, Section 3. The plan shall include the manufacturer's spare parts list for each CEMS and require that those parts be kept at the facility unless the Commissioner gives written approval to exclude specific spare parts from the list. [40 CFR pt. 60, Appendix F, 3, Minn. R. 7017.1170, subp. 2]

5.4.10 CEMS QA/QC: The owner or operator of an affected facility is subject to the performance specifications listed in 40 CFR pt. 60, Appendix B and shall operate, calibrate, and maintain each CEMS according to the QA/QC procedures in 40 CFR pt. 60, Appendix F as amended and maintain a written QA/QC program available in a form suitable for inspection. [40 CFR 60.13(a), 40 CFR pt. 60, Appendix F]

5.4.11 CEMS Daily Calibration Drift Test: Check the zero (low level value between 0 and 20 percent of span value) and span (50 to 100 percent of span value) calibration drifts at least once daily. The zero and span must, at a minimum, be adjusted whenever the drift exceeds two times the limit specified in 40 CFR pt. 60, Appendix B. 40 CFR pt. 60, Appendix F, Section 4.3.1 shall be



used to determine out-of-control periods for CEMS. [40 CFR 60.13(d)(1), 40 CFR pt. 60, Appendix F, 4.1, Minn. R. 7017.1170, subp. 3]

5.4.12 Recordkeeping: The owner or operator must retain records of all CEMS monitoring data and support information for a period of five years from the date of the monitoring sample, measurement or report. Records shall be kept at the source. [40 CFR 60.7(f), Minn. R. 7017.1130]

5.4.13 CEMS Certification/Recertification Test: due 90 days after the first excess emissions report required for the CEMS or any change which invalidates the monitor's certification status as outlined in Minn. R. 7017.1050, subp. 2. [40 CFR 60.13(b)]

EQUI 5 EU002 Combustion Turbine #2

5.5.1 Nitrogen Oxides: less than or equal to the value determined by the following equation: STD = 0.0075 * (14.4/Y) + F STD = NOx limit in percent by volume at 15 percent oxygen and on a dry basis Y = manufacturer's rated heat rate at manufacturer's rated load in kilojoules per watt hour, or actual measured heat rate based on lower heating value of fuel as measured at actual peak load, not to exceed 14.4 kilojoules per watt hour F = NOx emission allowance for fuel-bound nitrogen The use of F (fuel-bound nitrogen allowance) is optional. [40 CFR 60.332(a)(1), Minn. R. 7011.2350]

5.5.2 The Permittee shall limit Sulfur Dioxide <= 0.015 percent by volume at 15 percent oxygen and on a dry basis, or The Permittee shall limit Sulfur Content of Fuel <= 0.8 percent by weight. [40 CFR 60.333, Minn. R. 7011.2350]

5.5.3 The Permittee shall limit Sulfur Dioxide <= 0.50 pounds per million Btu heat input The potential to emit from the unit is 0.0022409 lb/MMBtu due to equipment design and allowable fuels. [Minn. R. 7011.2300, subp. 2]

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

5.5.5 Permitted Fuel Types: Natural gas as defined in 40 CFR Section 72.2, except total sulfur content shall not exceed 0.8 grains/100 scf and the natural gas shall be obtained from a supplier through a pipeline, and distillate fuel oil with a sulfur content not to exceed 0.05% by weight. [Minn. R. 7011.2300, subp. 2, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.5.6 The Permittee shall limit Operating Hours <= 875 hours per year 12-month rolling sum while using distillate fuel oil. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.5.7 NOx Monitoring: The Permittee shall use a CEM to measure



NOx emissions according to 40 CFR Sections 60.334(d) and (e), or continuously measure the water to fuel or steam to fuel ratio as described in 40 CFR Section 60.334(a). [40 CFR 60.334(d) & (e), Minn. R. 7011.2350]

5.5.8 Fuel Monitoring: The Permittee shall follow the applicable fuel sulfur and nitrogen content monitoring requirements in 40 CFR Section 60.334(h) and shall monitor at the frequency specified in 40 CFR Section 60.334(i). [40 CFR 60.334(h) & (i), Minn. R. 7011.2350]

5.5.9 Recordkeeping - Fuel Oil Operating Hours: Once each day the Permittee shall calculate and record the number of hours, to the nearest tenth, that the combustion turbine combusted fuel oil, during the previous calendar day. By the last day of each month, the Permittee shall calculate and record the total fuel oil combustion operating hours for the combustion turbine, for the previous calendar month and the previous 12-month period. Separate daily, monthly, and 12-month rolling sum records shall be kept for the combustion turbine. [Minn. R. 7007.0800, subps. 4-5, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.5.10 Excess Emission Reports: The Permittee shall submit reports of excess emissions required by 40 CFR Section 60.334(j) with the EER required for STRU 14 listed in this permit. [40 CFR 60.334(j), Minn. R. 7011.2350]

5.5.11 Performance Testing: The Permittee shall conduct performance testing to measure NOx and SO2, as required by 40 CFR Section 60.335, unless the Permittee obtains approval from the Administrator to use alternate test methods according to 40 CFR Section 60.8(b). [40 CFR 60.335, 40 CFR 60.8(a), Minn. R. 7011.2350]

5.5.12 The Permittee shall keep records of fuel type and usage on a monthly basis. [Minn. R. 7007.0800, subp. 5]

5.5.13 For the purposes of the 40 CFR pt. 97, subp. AAAAA requirements in this permit, the "Permittee" is an "owner" and "operator" as defined in 40 CFR Section 97.402. [Minn. R. 7007.0800, subp. 2]

5.5.14 Transport Rule (TR) NOx Annual Trading Program Requirements. The Permittee shall comply with the TR NOx Annual Trading Program requirements contained in Appendix D. [40 CFR 97.430-435]

5.5.15 Designated representative requirements. The owners and operators shall comply with the requirement to have a designated representative, and may have an alternate designated representative, in accordance with 40 CFR Sections 97.413 through 97.418. [40 CFR 97.406(a)]

5.5.16 TR NOx Emissions monitoring, reporting, and recordkeeping requirements. 1) The owners and operators and the designated



representative of each TR NOx Annual source and each TR NOx Annual unit at the source shall comply with the monitoring, reporting, and recordkeeping requirements of 40 CFR Section 97.430 (general requirements, including installation, certification, and data accounting, compliance deadlines, reporting data, prohibitions, and long-term cold storage), 40 CFR Section 97.431 (initial monitoring system certification and recertification procedures), 40 CFR Section 97.432 (monitoring system out-of-control periods), 40 CFR Section 97.433 (notifications concerning monitoring), 40 CFR Section 97.434 (recordkeeping and reporting, including monitoring plans, certification applications, quarterly reports, and compliance certification), and 40 CFR Section 97.435 (petitions for alternatives to monitoring, recordkeeping, or reporting requirements). 2) The emissions data determined in accordance with 40 CFR Section 97.430 through 97.435 shall be used to calculate allocations of TR NOx Annual allowances under 40 CFR Section 97.411(a)(2) and (b) and 40 CFR Section 97.412 and to determine compliance with the TR NOx Annual emissions limitation and assurance provisions under paragraph 40 CFR Section 97.406(c) below, provided that, for each monitoring location from which mass emissions are reported, the mass emissions amount used in calculating such allocations and determining such compliance shall be the mass emissions amount for the monitoring location determined in accordance with 40 CFR Section 97.430 through 97.435 and rounded to the nearest ton, with any fraction of a ton less than 0.50 being deemed to be zero. [40 CFR 97.406(b)]

5.5.17 TR NOx Annual emissions limitation. i) As of the allowance transfer deadline (midnight of March 1 (if it is a business day), or midnight of the first business day thereafter (if March 1 is not a business day)) for a control period in a given year, the owners and operators of each TR NOx Annual source and each TR NOx Annual unit at the source shall hold, in the source's compliance account, TR NOx Annual allowances available for deduction for such control period under 40 CFR Section 97.424(a) in an amount not less than the tons of total NOx emissions for such control period from all TR NOx Annual units at the source. ii) If total NOx emissions during a control period in a given year from the TR NOx Annual units at a TR NOx Annual source are in excess of the TR NOx Annual emissions limitation set forth in 40 CFR Section 97.406(c)(1)(i) above, then: A) The owners and operators of the source and each TR NOx Annual unit at the source shall hold the TR NOx Annual allowances required for deduction under 40 CFR Section 97.424(d); and B) The owners and operators of the source and each TR NOx Annual unit at the source shall pay any fine, penalty, or assessment or comply with any other remedy imposed, for the same violations, under the Clean Air Act, and each ton of such excess emissions and each day of such control period shall constitute a separate



violation of 40 CFR part 97, subpart AAAAA and the Clean Air Act. [40 CFR 97.406(c)(1)]

5.5.18 TR NOx Annual assurance provisions. i) If total NOx emissions during a control period in a given year from all TR NOx Annual units at TR NOx Annual sources in Minnesota and Indian country within the borders of Minnesota exceed the state assurance level, then the owners and operators of such sources and units in each group of one or more sources and units having a common designated representative for such control period, where the common designated representative's share of such NOx emissions during such control period exceeds the common designated representative's assurance level for the state and such control period, shall hold (in the assurance account established for the owners and operators of such group) TR NOx Annual allowances available for deduction for such control period under 40 CFR Section 97.425(a) in an amount equal to two times the product (rounded to the nearest whole number), as determined by the Administrator in accordance with 40 CFR Section 97.425(b), of multiplying- A) The quotient of the amount by which the common designated representative's share of such NOx emissions exceeds the common designated representative's assurance level divided by the sum of the amounts, determined for all common designated representatives for such sources and units in the Minnesota and Indian country within the borders of Minnesota for such control period, by which each common designated representative's share of such NOx emissions exceeds the respective common designated representative's assurance level; and B) The amount by which total NOx emissions from all TR NOx Annual units at TR NOx Annual sources in Minnesota and Indian country within the borders of Minnesota for such control period exceed the state assurance level. ii) The owners and operators shall hold the TR NOx Annual allowances required under 40 CFR Section 97.406(c)(2)(i) above, as of midnight of November 1 (if it is a business day), or midnight of the first business day thereafter (if November 1 is not a business day), immediately after such control period. iii) Total NOx emissions from all TR NOx Annual units at TR NOx Annual sources in Minnesota and Indian country within in the borders of Minnesota during a control period in a given year exceed the state assurance level if such total NOx emissions exceed the sum, for such control period, of the state NOx Annual trading budget under 40 CFR Section 97.410(a) and the state's variability limit under 40 CFR Section 97.410(b). iv) It shall not be a violation of 40 CFR part 97, subpart AAAAA or of the Clean Air Act if total NOx emissions from all TR NOx Annual units at TR NOx Annual sources in Minnesota and Indian country within the borders of Minnesota during a control period exceed the state assurance level or if a common designated representative's share of total NOx emissions from the TR NOx Annual units at TR NOx Annual sources in the



Minnesota and Indian country within the borders of Minnesota during a control period exceeds the common designated representative's assurance level. v) To the extent the owners and operators fail to hold TR NOx Annual allowances for a control period in a given year in accordance with 40 CFR Section 97.406(c)(2)(i) through (iii) above, A. The owners and operators shall pay any fine, penalty, or assessment or comply with any other remedy imposed under the Clean Air Act; and B. Each TR NOx Annual allowance that the owners and operators fail to hold for such control period in accordance with 40 CFR Section 97.406(c)(2)(i) through (iii) above and each day of such control period shall constitute a separate violation of 40 CFR part 97, subpart AAAAA and the Clean Air Act. [40 CFR 97.406(c)(2)(i)-(v)]

5.5.19 Compliance periods. i) A TR NOx Annual unit shall be subject to the requirements under 40 CFR Section 97.406(c)(1) above for the control period starting on the later of January 1, 2015, or the deadline for meeting the unit's monitor certification requirements under 40 CFR 97.430(b) and for each control period thereafter. ii) A TR NOx Annual unit shall be subject to the requirements under 40 CFR Section 97.406(c)(2) above for the control period starting on the later of January 1, 2017 or the deadline for meeting the unit's monitor certification requirements under 40 CFR 97.430(b) and for each control period thereafter. [40 CFR 97.406(c)(3)]

5.5.20 Vintage of allowances held for compliance. i) A TR NOx Annual allowance held for compliance with the requirements under 40 CFR Section 97.406(c)(1)(i) above for a control period in a given year must be a TR NOx Annual allowance that was allocated for such control period or a control period in a prior year. ii) A TR NOx Annual allowance held for compliance with the requirements under 40 CFR Section 97.406(c)(1)(ii)(A) and (2)(i) through (iii) above for a control period in a given year must be a TR NOx Annual allowance that was allocated for a control period in a prior year or the control period in the given year or in the immediately following year. [40 CFR 97.406(c)(4)]

5.5.21 Allowance Management System requirements. Each TR NOx Annual allowance shall be held in, deducted from, or transferred into, out of, or between Allowance Management System accounts in accordance with 40 CFR part 97, subpart AAAAA. [40 CFR 97.406(c)(5)]

5.5.22 Limited authorization. A TR NOx Annual allowance is a limited authorization to emit one ton of NOx during the control period in one year. Such authorization is limited in its use and duration as follows: i) Such authorization shall only be used in accordance with the TR NOx Annual Trading Program; and ii) Notwithstanding any other provision of 40 CFR part 97, the



Administrator has the authority to terminate or limit the use and duration of such authorization to the extent the Administrator determines is necessary or appropriate to implement any provision of the Clean Air Act. [40 CFR 97.406(c)(6)]

5.5.23 Property right. A TR NOx Annual allowance does not constitute a property right. [40 CFR 97.406(c)(7)]

5.5.24 Additional recordkeeping and reporting requirements. 1) Unless otherwise provided, the owners and operators of each TR NOx Annual source and each TR NOx Annual unit at the source shall keep on site at the source each of the following documents (in hardcopy or electronic format) for a period of 5 years from the date the document is created. This period may be extended for cause, at any time before the end of 5 years, in writing by the Administrator. i) The certificate of representation under 40 CFR Section 97.416 for the designated representative for the source and each TR NOx Annual unit at the source and all documents that demonstrate the truth of the statements in the certificate of representation; provided that the certificate and documents shall be retained on site at the source beyond such 5-year period until such certificate of representation and documents are superseded because of the submission of a new certificate of representation under 40 CFR Section 97.416 changing the designated representative. ii) All emissions monitoring information, in accordance with 40 CFR part 97, subpart AAAAA. iii) Copies of all reports, compliance certifications, and other submissions and all records made or required under, or to demonstrate compliance with the requirements of, the TR NOx Annual Trading Program. 2) The designated representative of a TR NOx Annual source and each TR NOx Annual unit at the source shall make all submissions required under the TR NOx Annual Trading Program, except as provided in 40 CFR Section 97.418. This requirement does not change, create an exemption from, or otherwise affect the responsible official submission requirements under a title V operating permit program in 40 CFR parts 70 and 71. [40 CFR 97.406(e)]

5.5.25 Liability. 1) Any provision of the TR NOx Annual Trading Program that applies to a TR NOx Annual source or the designated representative of a TR NOx Annual source shall also apply to the owners and operators of such source and of the TR NOx Annual unit shall also apply to the owners and operators of such unit. 2) Any provision of the TR NOx Annual Trading Program that applies to a TR NOx Annual unit or the designated representative of a TR NOx Annual unit shall also apply to the owners and operators of such unit. [40 CFR 97.406(f)]

5.5.26 Effect on other authorities. No provision of the TR NOx Annual Trading Program or



exemption under 40 CFR Section 97.405 shall be construed as exempting or excluding the owners and operators, and the designated representative, of a TR NOx Annual source or TR NOx Annual unit from compliance with any other provision of the applicable, approved state implementation plan, a federally enforceable permit, or the Clean Air Act. [40 CFR 97.406(g)]

5.5.27 Transport Rule (TR) SO2 Group 2 Trading Program Requirements. The Permittee shall comply with the TR SO2 Group 2 Trading Program Requirements contained in Appendix D. [40 CFR 97.730-735]

5.5.28 Designated representative requirements. The owners and operators shall comply with the requirement to have a designated representative, and may have an alternate designated representative, in accordance with 40 CFR Section 97.713 through 97.718. [40 CFR 97.706(a)]

5.5.29 TR SO2 Group 2 Emissions monitoring, reporting, and recordkeeping requirements. 1) The owners and operators, and the designated representative, of each TR SO2 Group 2 source and each TR SO2 Group 2 unit at the source shall comply with the monitoring, reporting, and recordkeeping requirements of 40 CFR Section 97.730 (general requirements, including installation, certification, and data accounting, compliance deadlines, reporting data, prohibitions, and long-term cold storage), 40 CFR Section 97.731 (initial monitoring system certification and recertification procedures), 40 CFR Section 97.732 (monitoring system out-of-control periods), 40 CFR Section 97.733 (notifications concerning monitoring), 40 CFR Section 97.734 (recordkeeping and reporting, including monitoring plans, certification applications, quarterly reports, and compliance certification), and 40 CFR Section 97.735 (petitions for alternatives to monitoring, recordkeeping, or reporting requirements). 2) The emissions data determined in accordance with 40 CFR Section 97.730 through 97.735 shall be used to calculate allocations of TR SO2 Group 2 allowances under 40 CFR Section 97.711(a)(2) and (b) and 40 CFR Section 97.712 and to determine compliance with the TR SO2 Group 2 emissions limitation and assurance provisions under paragraph (c) below, provided that, for each monitoring location from which mass emissions are reported, the mass emissions amount used in calculating such allocations and determining such compliance shall be the mass emissions amount for the monitoring location determined in accordance with 40 CFR Section 97.730 through 97.735 and rounded to the nearest ton, with any fraction of a ton less than 0.50 being deemed to be zero. [40 CFR 97.706(b)]

5.5.30 TR SO2 Group 2 emissions limitation. i) As of the allowance transfer deadline (midnight of March 1 (if it is a business day), or midnight of the first business day



thereafter (if March 1 is not a business day)) for a control period in a given year, the owners and operators of each TR SO2 Group 2 source and each TR SO2 Group 2 unit at the source shall hold, in the source's compliance account, TR SO2 Group 2 allowances available for deduction for such control period under 40 CFR Section 97.724(a) in an amount not less than the tons of total SO2 emissions for such control period from all TR SO2 Group 2 units at the source. ii) If total SO2 emissions during a control period in a given year from the TR SO2 Group 2 units at a TR SO2 Group 2 source are in excess of the TR SO2 Group 2 emissions limitation set forth in paragraph 40 CFR Section 97.706(c)(1)(i) above, then: A) The owners and operators of the source and each TR SO2 Group 2 unit at the source shall hold the TR SO2 Group 2 allowances required for deduction under 40 CFR Section 97.724(d); and B) The owners and operators of the source and each TR SO2 Group 2 unit at the source shall pay any fine, penalty, or assessment or comply with any other remedy imposed, for the same violations, under the Clean Air Act, and each ton of such excess emissions and each day of such control period shall constitute a separate violation of 40 CFR part 97, subpart DDDDD and the Clean Air Act. [40 CFR 97.706(c)(1)]

5.5.31 TR SO2 Group 2 assurance provisions. â€‹i) If total SO2 emissions during a control period in a given year from all TR SO2 Group 2 units at TR SO2 Group 2 sources in Minnesota and Indian country within the borders of Minnesota exceed the state assurance level, then the owners and operators of such sources and units in each group of one or more sources and units having a common designated representative for such control period, where the common designated representative's share of such SO2 emissions during such control period exceeds the common designated representative's assurance level for the state and such control period, shall hold (in the assurance account established for the owners and operators of such group) TR SO2 Group 2 allowances available for deduction for such control period under 40 CFR Section 97.725(a) in an amount equal to two times the product (rounded to the nearest whole number), as determined by the Administrator in accordance with 40 CFR Section 97.725(b), of multiplying- A) The quotient of the amount by which the common designated representative's share of such SO2 emissions exceeds the common designated representative's assurance level divided by the sum of the amounts, determined for all common designated representatives for such sources and units in Minnesota and Indian country within the borders of Minnesota for such control period, by which each common designated representative's share of such SO2 emissions exceeds the respective common designated representative's assurance level; and B) The amount by which total SO2 emissions from all TR SO2 Group 2 units at TR SO2 Group 2 sources in Minnesota and Indian country within the borders of Minnesota for such



control period exceed the state assurance level. ii) The owners and operators shall hold the TR SO2 Group 2 allowances required under 40 CFR Section 97.706(c)(2)(i) above, as of midnight of November 1 (if it is a business day), or midnight of the first business day thereafter (if November 1 is not a business day), immediately after such control period. iii) Total SO2 emissions from all TR SO2 Group 2 units at TR SO2 Group 2 sources in Minnesota and Indian country within the borders of Minnesota during a control period in a given year exceed the state assurance level if such total SO2 emissions exceed the sum, for such control period, of the state SO2 Group 2 trading budget under 40 CFR Section 97.710(a) and the state's variability limit under 40 CFR Section 97.710(b). iv) It shall not be a violation of 40 CFR part 97, subpart DDDDD or of the Clean Air Act if total SO2 emissions from all TR SO2 Group 2 units at TR SO2 Group 2 sources in Minnesota and Indian country within the borders of Minnesota during a control period exceed the state assurance level or if a common designated representative's share of total SO2 emissions from the TR SO2 Group 2 units at TR SO2 Group 2 sources in Minnesota and Indian country within the borders of Minnesota during a control period exceeds the common designated representative's assurance level. v) To the extent the owners and operators fail to hold TR SO2 Group 2 allowances for a control period in a given year in accordance with 40 CFR Section 97.706(c)(2)(i) through (iii) above, A.) The owners and operators shall pay any fine, penalty, or assessment or comply with any other remedy imposed under the Clean Air Act; and B.) Each TR SO2 Group 2 allowance that the owners and operators fails to hold for such control period in accordance with 40 CFR Section 97.706(c)(2)(i) through (iii) above and each day of such control period shall constitute a separate violation of 40 CFR part 97, subpart DDDDD and the Clean Air Act. [40 CFR 97.706(c)(2)(i)-(v)]

5.5.32 Compliance Periods. i) A TR SO2 Group 2 unit shall be subject to the requirements under 40 CFR Section 97.706(c)(1) above for the control period starting on the later of January 1, 2015 or the deadline for meeting the unit's monitor certification requirements under 40 CFR Section 97.730(b) and for each control period thereafter ii) A TR SO2 Group 2 unit shall be subject to the requirements under 40 Section CFR 97.706(c)(2) above for the control period starting on the later of January 1, 2017 or the deadline for meeting the unit's monitor certification requirements under 40 CFR Section 97.730(b) and for each control period thereafter. [40 CFR 97.706(c)(3)]

5.5.33 Vintage of allowances held for compliance. i) A TR SO2 Group 2 allowance held for compliance with the requirements under 40 CFR Section 97.706(c)(1)(i) above for a control period in a given year must be a TR SO2 Group 2 allowance that was allocated for such control period or a



control period in a prior year. ii) A TR SO2 Group 2 allowance held for compliance with the requirements under 40 CFR Section 97.706(c)(1)(ii)(A) and (2)(i) through (iii) above for a control period in a given year must be a TR SO2 Group 2 allowance that was allocated for a control period in a prior year or the control period in the given year or in the immediately following year. [40 CFR 97.706(c)(4)]

5.5.34 Allowance Management System requirements. Each TR SO2 Group 2 allowance shall be held in, deducted from, or transferred into, out of, or between Allowance Management System accounts in accordance with 40 CFR part 97, subpart DDDDD. [40 CFR 97.706(c)(5)]

5.5.35 Limited authorization. A TR SO2 Group 2 allowance is a limited authorization to emit one ton of SO2 during the control period in one year. Such authorization is limited in its use and duration as follows: i) Such authorization shall only be used in accordance with the TR SO2 Group 2 Trading Program; and ii) Notwithstanding any other provision of 40 CFR part 97, subpart DDDDD, the Administrator has the authority to terminate or limit the use and duration of such authorization to the extent the Administrator determines is necessary or appropriate to implement any provision of the Clean Air Act. [40 CFR 97.706(c)(6)]

5.5.36 Property right. A TR SO2 Group 2 allowance does not constitute a property right. [40 CFR 97.706(c)(7)]

5.5.37 Additional recordkeeping and reporting requirements. 1) Unless otherwise provided, the owners and operators of each TR SO2 Group 2 source and each TR SO2 Group p2 unit at the source shall keep on site at the source each of the following documents (in hardcopy or electronic format) for a period of 5 years from the date the document is created. This period may be extended for cause, at any time before the end of 5 years, in writing by the Administrator. i) The certificate of representation under 40 CFR Section 97.716 for the designated representative for the source and each TR SO2 Group 2 unit at the source and all documents that demonstrate the truth of the statements in the certificate of representation; provided that the certificate and documents shall be retained on site at the source beyond such 5-year period until such certificate of representation and documents are superseded because of the submission of a new certificate of representation under 40 CFR Section 97.716 changing the designated representative. ii) All emissions monitoring information, in accordance with 40 CFR part 97, subpart DDDDD. iii) Copies of all reports, compliance certifications, and other submissions and all records made or required under, or to demonstrate compliance with the requirements of, the TR SO2 Group 2 Trading Program.



2) The designated representative of a TR SO2 Group 2 source and each TR SO2 Group 2 unit at the source shall make all submissions required under the TR SO2 Group 2 Trading Program, except as provided in 40 CFR Section 97.718. This requirement does not change, create an exemption from, or otherwise affect the responsible official submission requirements under a title V operating permit program in parts 70 and 71. [40 CFR 97.706(e)]

5.5.38 Liability. 1) Any provision of the TR SO2 Group 2 Trading Program that applies to a TR SO2 Group 2 source or the designated representative of a TR SO2 Group 2 source shall also apply to the owners and operators of such source and of the TR SO2 Group 2 units at the source. 2) Any provision of the TR SO2 Group 2 Trading Program that applies to a TR SO2 Group 2 unit or the designated representative of a TR SO2 Group 2 unit shall also apply to the owners and operators of such unit. [40 CFR 97.706(f)]

5.5.39 Effect on other authorities. No provision of the TR SO2 Group 2 Trading Program or exemption under 40 CFR Section 97.705 shall be construed as exempting or excluding the owners or operators, and the designated representative, of a TR SO2 Group 2 source or TR SO2 Group 2 unit from compliance with any other provision of the applicable, approved state implementation plan, a federally enforceable permit, or the Clean Air Act. [40 CFR 97.706(g)]

5.5.40 Additional requirements for Combustion Turbine #2 are located at STRU 14. [Minn. R. 7007.0800, subp. 2]

EQUI 6 EU004 Duct Burner (Combustion Turbine #2)

5.6.1 The Permittee shall limit Sulfur Dioxide <= 0.20 pounds per million Btu heat input 30-day rolling average except during startup, shutdown, or malfunction. '30-day Rolling Average' is '30 successive boiler operating days rolling average', and 'boiler operating day' is defined at 40 CFR Section 60.41Da. [40 CFR 60.43Da(b)(2), 40 CFR 60.48Da(a) & (b), Minn. R. 7011.0560]

5.6.2 The Permittee shall limit Nitrogen Oxides <= 1.6 pounds per megawatt-hour 30-day rolling average except during startup, shutdown, or malfunction, or, The Permittee shall limit Nitrogen Oxides <= 0.15 lb/million Btu using 30-day Rolling Average except during startup, shutdown, or malfunction. '30-day Rolling Average' is '30 successive boiler operating days rolling average', and 'boiler operating day' is defined at 40 CFR Section 60.41Da. Megawatt-hour is on a gross output basis.



[40 CFR 60.44Da(d), 40 CFR 60.48Da(a) & (b), Minn. R. 7011.0560]

5.6.3 Permitted Fuel Type: Natural gas as defined in 40 CFR Section 72.2, except total sulfur content shall not exceed 0.8 grains/100 scf and the natural gas shall be obtained from a supplier through a pipeline. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.6.4 Fuel Supplier Certification: The Permittee shall obtain and maintain annual fuel supplier certification for pipeline delivery of natural gas, certifying that the sulfur content does not exceed 0.8 grains/100 scf. [Minn. R. 7007.0800, subps. 4-5, Title I Condition: 40 CFR pt. 52, 21(j)(BACT) & Minn. R. 7007.3000]

5.6.5 Duct Burner Compliance Provisions: The Permittee shall follow the compliance provisions in 40 CFR Section 60.48Da to determine duct burner compliance with the SO2 limit in 40 CFR Section 60.42Da(b)(2) and the NOx limit in 40 CFR Section 60.44Da(d). [40 CFR 60.48Da, Minn. R. 7011.0560]

5.6.6 Reporting: Follow reporting requirements in 40 CFR Section 60.49Da as applicable. [40 CFR 60.49Da, Minn. R. 7011.0560]




5.6.10 TR NOx Emissions monitoring, reporting, and recordkeeping requirements. 1) The owners and operators and the designated representative of each TR NOx Annual source and each TR NOx Annual unit at the source shall comply with the monitoring, reporting, and recordkeeping requirements of 40 CFR Section 97.430 (general requirements, including installation, certification, and data accounting, compliance deadlines, reporting data, prohibitions, and long-term cold storage), 40 CFR Section 97.431 (initial monitoring system certification and recertification procedures), 40 CFR Section 97.432 (monitoring system out-of-control periods), 40 CFR Section 97.433 (notifications concerning monitoring), 40 CFR Section 97.434 (recordkeeping and reporting, including monitoring plans, certification applications, quarterly reports, and compliance certification), and 40 CFR Section 97.435 (petitions for alternatives to monitoring, recordkeeping, or reporting requirements).



2) The emissions data determined in accordance with 40 CFR Section 97.430 through 97.435 shall be used to calculate allocations of TR NOx Annual allowances under 40 CFR Section 97.411(a)(2) and (b) and 40 CFR Section 97.412 and to determine compliance with the TR NOx Annual emissions limitation and assurance provisions under paragraph 40 CFR Section 97.406(c) below, provided that, for each monitoring location from which mass emissions are reported, the mass emissions amount used in calculating such allocations and determining such compliance shall be the mass emissions amount for the monitoring location determined in accordance with 40 CFR Section 97.430 through 97.435 and rounded to the nearest ton, with any fraction of a ton less than 0.50 being deemed to be zero. [40 CFR 97.406(b)]

5.6.11 TR NOx Annual emissions limitation. i) As of the allowance transfer deadline (midnight of March 1 (if it is a business day), or midnight of the first business day thereafter (if March 1 is not a business day)) for a control period in a given year, the owners and operators of each TR NOx Annual source and each TR NOx Annual unit at the source shall hold, in the source's compliance account, TR NOx Annual allowances available for deduction for such control period under 40 CFR Section 97.424(a) in an amount not less than the tons of total NOx emissions for such control period from all TR NOx Annual units at the source. ii) If total NOx emissions during a control period in a given year from the TR NOx Annual units at a TR NOx Annual source are in excess of the TR NOx Annual emissions limitation set forth in 40 CFR Section 97.406(c)(1)(i) above, then: A) The owners and operators of the source and each TR NOx Annual unit at the source shall hold the TR NOx Annual allowances required for deduction under 40 CFR Section 97.424(d); and B) The owners and operators of the source and each TR NOx Annual unit at the source shall pay any fine, penalty, or assessment or comply with any other remedy imposed, for the same violations, under the Clean Air Act, and each ton of such excess emissions and each day of such control period shall constitute a separate violation of 40 CFR part 97, subpart AAAAA and the Clean Air Act. [40 CFR 97.406(c)(1)]

5.6.12 TR NOx Annual assurance provisions. i) If total NOx emissions during a control period in a given year from all TR NOx Annual units at TR NOx Annual sources in Minnesota and Indian country within the borders of Minnesota exceed the state assurance level, then the owners and operators of such sources and units in each group of one or more sources and units having a common designated representative for such control period, where the common designated representative's share of such NOx emissions during such control period exceeds the common designated representative's assurance level for the state and such control period, shall hold (in the assurance account established for the owners and operators of such group) TR NOx Annual



allowances available for deduction for such control period under 40 CFR Section 97.425(a) in an amount equal to two times the product (rounded to the nearest whole number), as determined by the Administrator in accordance with 40 CFR Section 97.425(b), of multiplying- A) The quotient of the amount by which the common designated representative's share of such NOx emissions exceeds the common designated representative's assurance level divided by the sum of the amounts, determined for all common designated representatives for such sources and units in the Minnesota and Indian country within the borders of Minnesota for such control period, by which each common designated representative's share of such NOx emissions exceeds the respective common designated representative's assurance level; and B) The amount by which total NOx emissions from all TR NOx Annual units at TR NOx Annual sources in Minnesota and Indian country within the borders of Minnesota for such control period exceed the state assurance level. ii) The owners and operators shall hold the TR NOx Annual allowances required under 40 CFR Section 97.406(c)(2)(i) above, as of midnight of November 1 (if it is a business day), or midnight of the first business day thereafter (if November 1 is not a business day), immediately after such control period. iii) Total NOx emissions from all TR NOx Annual units at TR NOx Annual sources in Minnesota and Indian country within in the borders of Minnesota during a control period in a given year exceed the state assurance level if such total NOx emissions exceed the sum, for such control period, of the state NOx Annual trading budget under 40 CFR Section 97.410(a) and the state's variability limit under 40 CFR Section 97.410(b). iv) It shall not be a violation of 40 CFR part 97, subpart AAAAA or of the Clean Air Act if total NOx emissions from all TR NOx Annual units at TR NOx Annual sources in Minnesota and Indian country within the borders of Minnesota during a control period exceed the state assurance level or if a common designated representative's share of total NOx emissions from the TR NOx Annual units at TR NOx Annual sources in the Minnesota and Indian country within the borders of Minnesota during a control period exceeds the common designated representative's assurance level. v) To the extent the owners and operators fail to hold TR NOx Annual allowances for a control period in a given year in accordance with 40 CFR Section 97.406(c)(2)(i) through (iii) above, A. The owners and operators shall pay any fine, penalty, or assessment or comply with any other remedy imposed under the Clean Air Act; and B. Each TR NOx Annual allowance that the owners and operators fail to hold for such control period in accordance with 40 CFR Section 97.406(c)(2)(i) through (iii) above and each day of such control period shall constitute a separate violation of 40 CFR part 97, subpart AAAAA and the Clean Air Act. [40 CFR 97.406(c)(2)(i)-(v)]






5.6.16 Limited authorization. A TR NOx Annual allowance is a limited authorization to emit one ton of NOx during the control period in one year. Such authorization is limited in its use and duration as follows: i) Such authorization shall only be used in accordance with the TR NOx Annual Trading Program; and ii) Notwithstanding any other provision of 40 CFR part 97, the Administrator has the authority to terminate or limit the use and duration of such authorization to the extent the Administrator determines is necessary or appropriate to implement any provision of the Clean Air Act. [40 CFR 97.406(c)(6)]


5.6.18 Additional recordkeeping and reporting requirements. 1) Unless otherwise provided, the owners and operators of each TR NOx Annual source and each TR NOx Annual unit at the source shall keep on site at the source each of the following documents (in hardcopy or electronic format) for a period of 5 years from the date the document is created. This period may be extended for cause, at any time before the end of 5 years, in writing by the Administrator.



i) The certificate of representation under 40 CFR Section 97.416 for the designated representative for the source and each TR NOx Annual unit at the source and all documents that demonstrate the truth of the statements in the certificate of representation; provided that the certificate and documents shall be retained on site at the source beyond such 5-year period until such certificate of representation and documents are superseded because of the submission of a new certificate of representation under 40 CFR Section 97.416 changing the designated representative. ii) All emissions monitoring information, in accordance with 40 CFR part 97, subpart AAAAA. iii) Copies of all reports, compliance certifications, and other submissions and all records made or required under, or to demonstrate compliance with the requirements of, the TR NOx Annual Trading Program. 2) The designated representative of a TR NOx Annual source and each TR NOx Annual unit at the source shall make all submissions required under the TR NOx Annual Trading Program, except as provided in 40 CFR Section 97.418. This requirement does not change, create an exemption from, or otherwise affect the responsible official submission requirements under a title V operating permit program in 40 CFR parts 70 and 71. [40 CFR 97.406(e)]


5.6.20 Effect on other authorities. No provision of the TR NOx Annual Trading Program or exemption under 40 CFR Section 97.405 shall be construed as exempting or excluding the owners and operators, and the designated representative, of a TR NOx Annual source or TR NOx Annual unit from compliance with any other provision of the applicable, approved state implementation plan, a federally enforceable permit, or the Clean Air Act. [40 CFR 97.406(g)]


5.6.22 Designated representative requirements. The owners and operators shall comply with the requirement to have a designated representative, and may have an



alternate designated representative, in accordance with 40 CFR Section 97.713 through 97.718. [40 CFR 97.706(a)]


5.6.24 TR SO2 Group 2 emissions limitation. i) As of the allowance transfer deadline (midnight of March 1 (if it is a business day), or midnight of the first business day thereafter (if March 1 is not a business day)) for a control period in a given year, the owners and operators of each TR SO2 Group 2 source and each TR SO2 Group 2 unit at the source shall hold, in the source's compliance account, TR SO2 Group 2 allowances available for deduction for such control period under 40 CFR Section 97.724(a) in an amount not less than the tons of total SO2 emissions for such control period from all TR SO2 Group 2 units at the source. ii) If total SO2 emissions during a control period in a given year from the TR SO2 Group 2 units at a TR SO2 Group 2 source are in excess of the TR SO2 Group 2 emissions limitation set forth in paragraph 40 CFR Section 97.706(c)(1)(i) above, then: A) The owners and operators of the source and each TR SO2 Group 2 unit at the source shall hold the TR SO2 Group 2 allowances required for deduction under 40 CFR Section 97.724(d); and B)



The owners and operators of the source and each TR SO2 Group 2 unit at the source shall pay any fine, penalty, or assessment or comply with any other remedy imposed, for the same violations, under the Clean Air Act, and each ton of such excess emissions and each day of such control period shall constitute a separate violation of 40 CFR part 97, subpart DDDDD and the Clean Air Act. [40 CFR 97.706(c)(1)]

5.6.25 TR SO2 Group 2 assurance provisions. â€‹i) If total SO2 emissions during a control period in a given year from all TR SO2 Group 2 units at TR SO2 Group 2 sources in Minnesota and Indian country within the borders of Minnesota exceed the state assurance level, then the owners and operators of such sources and units in each group of one or more sources and units having a common designated representative for such control period, where the common designated representative's share of such SO2 emissions during such control period exceeds the common designated representative's assurance level for the state and such control period, shall hold (in the assurance account established for the owners and operators of such group) TR SO2 Group 2 allowances available for deduction for such control period under 40 CFR Section 97.725(a) in an amount equal to two times the product (rounded to the nearest whole number), as determined by the Administrator in accordance with 40 CFR Section 97.725(b), of multiplying- A) The quotient of the amount by which the common designated representative's share of such SO2 emissions exceeds the common designated representative's assurance level divided by the sum of the amounts, determined for all common designated representatives for such sources and units in Minnesota and Indian country within the borders of Minnesota for such control period, by which each common designated representative's share of such SO2 emissions exceeds the respective common designated representative's assurance level; and B) The amount by which total SO2 emissions from all TR SO2 Group 2 units at TR SO2 Group 2 sources in Minnesota and Indian country within the borders of Minnesota for such control period exceed the state assurance level. ii) The owners and operators shall hold the TR SO2 Group 2 allowances required under 40 CFR Section 97.706(c)(2)(i) above, as of midnight of November 1 (if it is a business day), or midnight of the first business day thereafter (if November 1 is not a business day), immediately after such control period. iii) Total SO2 emissions from all TR SO2 Group 2 units at TR SO2 Group 2 sources in Minnesota and Indian country within the borders of Minnesota during a control period in a given year exceed the state assurance level if such total SO2 emissions exceed the sum, for such control period, of the state SO2 Group 2 trading budget under 40 CFR Section 97.710(a) and the state's variability limit under 40 CFR Section 97.710(b). iv) It shall not be a violation of 40 CFR part 97, subpart DDDDD or of the Clean Air Act if total SO2 emissions from all TR SO2



Group 2 units at TR SO2 Group 2 sources in Minnesota and Indian country within the borders of Minnesota during a control period exceed the state assurance level or if a common designated representative's share of total SO2 emissions from the TR SO2 Group 2 units at TR SO2 Group 2 sources in Minnesota and Indian country within the borders of Minnesota during a control period exceeds the common designated representative's assurance level. v) To the extent the owners and operators fail to hold TR SO2 Group 2 allowances for a control period in a given year in accordance with 40 CFR Section 97.706(c)(2)(i) through (iii) above, A.) The owners and operators shall pay any fine, penalty, or assessment or comply with any other remedy imposed under the Clean Air Act; and B.) Each TR SO2 Group 2 allowance that the owners and operators fails to hold for such control period in accordance with 40 CFR Section 97.706(c)(2)(i) through (iii) above and each day of such control period shall constitute a separate violation of 40 CFR part 97, subpart DDDDD and the Clean Air Act. [40 CFR 97.706(c)(2)(i)-(v)]


5.6.27 Vintage of allowances held for compliance. i) A TR SO2 Group 2 allowance held for compliance with the requirements under 40 CFR Section 97.706(c)(1)(i) above for a control period in a given year must be a TR SO2 Group 2 allowance that was allocated for such control period or a control period in a prior year. ii) A TR SO2 Group 2 allowance held for compliance with the requirements under 40 CFR Section 97.706(c)(1)(ii)(A) and (2)(i) through (iii) above for a control period in a given year must be a TR SO2 Group 2 allowance that was allocated for a control period in a prior year or the control period in the given year or in the immediately following year. [40 CFR 97.706(c)(4)]


5.6.29 Limited authorization. A TR SO2 Group 2 allowance is a limited authorization to emit



one ton of SO2 during the control period in one year. Such authorization is limited in its use and duration as follows: i) Such authorization shall only be used in accordance with the TR SO2 Group 2 Trading Program; and ii) Notwithstanding any other provision of 40 CFR part 97, subpart DDDDD, the Administrator has the authority to terminate or limit the use and duration of such authorization to the extent the Administrator determines is necessary or appropriate to implement any provision of the Clean Air Act. [40 CFR 97.706(c)(6)]


5.6.31 Additional recordkeeping and reporting requirements. 1) Unless otherwise provided, the owners and operators of each TR SO2 Group 2 source and each TR SO2 Group p2 unit at the source shall keep on site at the source each of the following documents (in hardcopy or electronic format) for a period of 5 years from the date the document is created. This period may be extended for cause, at any time before the end of 5 years, in writing by the Administrator. i) The certificate of representation under 40 CFR Section 97.716 for the designated representative for the source and each TR SO2 Group 2 unit at the source and all documents that demonstrate the truth of the statements in the certificate of representation; provided that the certificate and documents shall be retained on site at the source beyond such 5-year period until such certificate of representation and documents are superseded because of the submission of a new certificate of representation under 40 CFR Section 97.716 changing the designated representative. ii) All emissions monitoring information, in accordance with 40 CFR part 97, subpart DDDDD. iii) Copies of all reports, compliance certifications, and other submissions and all records made or required under, or to demonstrate compliance with the requirements of, the TR SO2 Group 2 Trading Program. 2) The designated representative of a TR SO2 Group 2 source and each TR SO2 Group 2 unit at the source shall make all submissions required under the TR SO2 Group 2 Trading Program, except as provided in 40 CFR Section 97.718. This requirement does not change, create an exemption from, or otherwise affect the responsible official submission requirements under a title V operating permit program in parts 70 and 71. [40 CFR 97.706(e)]

5.6.32 Liability. 1) Any provision of the TR SO2 Group 2 Trading Program that applies to a TR SO2 Group 2 source or the designated representative of a TR SO2 Group 2 source shall also apply to the owners and operators of such source and of the TR SO2 Group 2 units at the source. 2) Any provision of the TR SO2 Group 2 Trading Program that



applies to a TR SO2 Group 2 unit or the designated representative of a TR SO2 Group 2 unit shall also apply to the owners and operators of such unit. [40 CFR 97.706(f)]


5.6.34 Additional requirements for Duct Burner (Combustion Turbine #2) are located at STRU 14. [Minn. R. 7007.0800, subp. 2]

EQUI 7 EU005 Auxiliary Boiler

5.7.1 Total Particulate Matter <= 0.008 pounds per million Btu heat input 3-hour block average. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.7.2 PM < 10 micron <= 0.008 pounds per million Btu heat input 3-hour block average. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.7.3 Nitrogen Oxides <= 0.036 pounds per million Btu heat input 3-hour block average. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.7.4 Sulfur Dioxide <= 0.001 pounds per million Btu heat input 3-hour block average. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.7.5 Carbon Monoxide <= 0.06 pounds per million Btu heat input 3-hour block average. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.7.6 Volatile Organic Compounds <= 0.007 pounds per million Btu heat input 3-hour block average. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.7.7 Permitted Fuel Type: Restricted to natural gas with a sulfur content no greater than 0.8 grains per 100 scf. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.7.8 Fuel Usage Recordkeeping: Record and maintain records of the amounts fuel combusted on a monthly basis. These records may be in the form of fuel bills or meter readings. [40 CFR 60.48c(g)(2), Minn. R. 7011.0570]

EQUI 11 EU007 Fire Pump Engine

5.8.1 EQUI 11 is a 350 hp existing compression ignition reciprocating internal combustion engine (RICE) for which construction commenced prior to June 12, 2006 and is located at an area source of hazardous air pollutants (HAPs). [40 CFR 63.6590(a)(1)(iii), Minn. R. 7011.8150]

5.8.2 The Permittee shall comply with the applicable requirements for EQUI 11 under 40 CFR pt. 63, subp. ZZZZ no later than May 3, 2013. [40 CFR 63.6595(a), Minn. R. 7011.8150]



5.8.3 Part 63, Subpart ZZZZ Table 2d Requirements: 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 c. Inspect all hoses and belts every 500 hours of operation or annually, whichever comes first, and replace as necessary. [40 CFR 63.6603(a), 40 CFR pt. 63, subp. ZZZZ(Table 2d), Minn. R. 7011.8150]

5.8.4 The Permittee shall be in compliance with the emission limitations and operating limitations in 40 CFR pt. 63, subp. ZZZZ that apply to EQUI 11 at all times. [40 CFR 63.6605(a), Minn. R. 7011.8150]

5.8.5 At all times the Permittee must operate and maintain any affected source, including associated air pollution control equipment and monitoring equipment, 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 this standard 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 the source. [40 CFR 63.6605(b), Minn. R. 7011.8150]

5.8.6 The Permittee must operate and maintain EQUI 11 and after-treatment control device (if any) according to the manufacturer's emission-related written instructions, or develop a maintenance plan which must provide to the extent practicable for the maintenance and operation of EQUI 11 in a manner consistent with good air pollution control practice for minimizing emissions. [40 CFR 63.6625(e)(3), Minn. R. 7011.8150]

5.8.7 The Permittee shall install a non-resettable hour meter on EQUI 11 if one is not already installed. [40 CFR 63.6625(f), Minn. R. 7011.8150]

5.8.8 The Permittee shall minimize EQUI 11 time spent at idle during startup and minimize EQUI 11 startup time to a period needed for appropriate and safe loading of EQUI 11, not to exceed 30 minutes, after which time the emission standards applicable to all times other than startup in Table 2d in 40 CFR pt. 63, subp. ZZZZ apply. [40 CFR 63.6625(h), Minn. R. 7011.8150]

5.8.9 The Permittee has the option of utilizing an oil analysis program in order to extend the specified oil change requirement in Table 2d to 40 CFR pt. 63, subp. ZZZZ. The oil analysis must be performed at the same frequency specified for changing the oil in Table 2d to 40 CFR pt. 63, subp. ZZZZ. 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 days of receiving the results of the analysis; if EQUI 11 is not in operation when the results of the analysis are received, the Permittee must change the oil within 2 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 EQUI 11. The analysis program must be part of the maintenance plan for EQUI 11. [40 CFR 63.6625(i), Minn. R. 7011.8150]

5.8.10 The Permittee must demonstrate continuous compliance with each emission limitation and operating limitation in Table 2d to 40 CFR pt. 63, subp. ZZZZ that applies to EQUI 11 according to methods specified in item 9 in Table 6 to 40 CFR pt. 63, subp. ZZZZ. [40 CFR 63.6640(a), Minn. R. 7011.8150]

5.8.11 The Permittee must also report each instance in which the Permittee did not meet the applicable requirements for EQUI 11 in Table 8 of 40 CFR pt. 63, subp. ZZZZ. [40 CFR 63.6640(e), Minn. R. 7011.8150]

5.8.12 The Permittee must operate EQUI 11 according to the requirements in 40 CFR Section 63.6640(f)(1) through (4). Any operation other than emergency operation, maintenance and testing, and operation in nonemergency situations for 50 hours per year, as described in 40 CFR Section 63.6640(f)(1) through (4), is prohibited. If the Permittee does not operate EQUI 11 according to the requirements in 40 CFR Section 63.6640(f)(1) through (4), EQUI 11 will not be considered an emergency engine under 40 CFR pt. 63, subp. ZZZZ and will need to meet all requirements for non-emergency engines. [40 CFR 63.6640(f), Minn. R. 7011.8150]

5.8.13 There is no time limit on the use of EQUI 11 in emergency situations. [40 CFR 63.6640(f)(1), Minn. R. 7011.8150]

5.8.14 The Permittee may operate EQUI 11 for any combination of the purposes specified in 40 CFR Section 63.6640(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 Section 63.6640(f)(3) and (4) counts as part of the 100 hours per calendar year allowed by 40 CFR Section 63.6640(f)(2). [40 CFR 63.6640(f)(2), Minn. R. 7011.8150]

5.8.15 The Permittee may operate EQUI 11 for the purpose of maintenance checks and readiness testing, provided that the tests are recommended by Federal, State or local government, the manufacturer, the vendor, or the insurance company associated with EQUI 11. Maintenance checks and readiness testing of such units is limited to 100 hours per year. The



Permittee may petition the Administrator for approval of additional 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 emergency RICE beyond 100 hours per year. [40 CFR 63.6640(f)(2)(i), Minn. R. 7011.8150]

5.8.16 EQUI 11 may be operated for up to 50 hours per calendar year in non-emergency situations. The 50 hours of operation in non-emergency situations are counted as part of the 100 hours per calendar year for maintenance and testing provided in 40 CFR Section 63.6640(f)(2)(i). [40 CFR 63.6640(f)(4), Minn. R. 7011.8150]

5.8.17 The requirement to submit all of the notifications in 40 CFR Sections 63.7(b) and (c), 63.8(e), (f)(4) and (f)(6), 63.9(b) through (e), and (g) and (h) do not apply to EQUI 11 (existing emergency RICE). [40 CFR 63.6645(a)(5), Minn. R. 7011.8150]

5.8.18 If EQUI 11 is operating during an emergency and it is not possible to shut down EQUI 11 in order to perform the management practice requirements on the schedule required in Table 2d of 40 CFR pt. 63, subp. ZZZZ, or if performing the management practice on the required schedule would otherwise pose an unacceptable risk under federal, state, or local law, the management practice can be delayed until the emergency is over or the unacceptable risk under federal, state, or local law has abated. The management 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 management practice on the schedule required and the federal, state or local law under which the risk was deemed unacceptable. [40 CFR pt. 63, subp. ZZZZ(Table 2d)(footnote 2)]

5.8.19 The Permittee shall keep the following records: (1) A copy of each notification and report that you submitted to comply with 40 CFR pt. 63, subp. ZZZZ, including all documentation supporting any Initial Notification or Notification of Compliance Status submitted, according to the requirement in 40 CFR Section 63.10(b)(2)(xiv). (2) Records of the occurrence and duration of each malfunction of operation (i.e., process equipment) or the air pollution control and monitoring equipment. (3) Records of performance tests and performance evaluations as required in 40 CFR Section 63.10(b)(2)(viii). (4) Records of all required maintenance performed on the air pollution control and monitoring equipment. (5) Records of actions taken during periods of malfunction to minimize emissions in accordance with 40 CFR Section 63.6605(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 63.6655(a), Minn. R. 7011.8150]

5.8.20 The Permittee must keep the records required in Table 6 of 40 CFR pt. 63, subp. ZZZZ to show continuous compliance with each applicable emission or operating limitation. [40 CFR 63.6655(d), Minn. R. 7011.8150]

5.8.21 The Permittee must keep records of the maintenance conducted on EQUI 11 in order to demonstrate that the Permittee operated and maintained EQUI 11 and after-treatment control device (if any) according to the Permittee's maintenance plan. [40 CFR 63.6655(e), Minn. R. 7011.8150]

5.8.22 If EQUI 11 does not meet the standards applicable to non-emergency engines, the Permittee must keep records of the hours of operation of EQUI 11 that is recorded through the non-resettable hour meter. The Permittee must 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), Minn. R. 7011.8150]

5.8.23 (a) Records must be in a form suitable and readily available for expeditious review according to 40 CFR Section 63.10(b)(1). (b) As specified in 40 CFR 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 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 40 CFR Section 63.10(b)(1). [40 CFR 63.6660, Minn. R. 7011.8150]


5.8.25 The Permittee shall limit Total Particulate Matter <= 0.07 grams per horsepower-hour 3-hour block average. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.8.26 The Permittee shall limit PM < 10 micron <= 0.07 grams per horsepower-hour 3-hour block average. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.8.27 The Permittee shall limit Sulfur Dioxide <= 0.14 grams per horsepower-hour 3-hour block average. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.8.28 The Permittee shall limit Sulfur Dioxide <= 0.50 pounds per million Btu heat input. The potential to emit from the unit is 0.04735 lb/MMBtu due to equipment design and allowable fuels. [Minn. R. 7011.2300, subp. 2]

5.8.29 The Permittee shall limit Nitrogen Oxides <= 5.70 grams per horsepower-hour 3-hour block average. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.8.30 The Permittee shall limit Carbon Monoxide <= 0.25 grams per horsepower-hour 3-hour block average. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]



5.8.31 The Permittee shall limit Volatile Organic Compounds <= 0.08 grams per horsepower-hour 3-hour block average. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.8.32 Permitted Fuel Type: Restricted to distillate fuel oil with a sulfur content no greater than 0.05% by weight. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.8.33 The Permittee shall limit Operating Hours <= 300 hours per year 12-month rolling sum calculated monthly by the last day of each month. Note this limit is pre-empted by the 100 hour per year limit prescribed by 40 CFR Section 63.6640(f)(2)(i) (except for emergency operation for which the 100 hour per year limit does not apply as prescribed by 40 CFR Section 63.6640(f)(1)). [Title I Condition: 40 CFR 52.21(k)(1)(i) & Minn. R. 7007.3000]

5.8.34 Monitoring - Distillate Fuel Oil Sulfur Content: The Permittee shall determine the sulfur content of all distillate fuel oil deliveries using one of the following options: 1. Obtain a supplier certification for each fuel oil delivery stating the percent sulfur by weight in the delivered distillate fuel oil; 2. Use the results of the 40 CFR part 75 Appendix D fuel oil sulfur determination requirements conducted for EQUI 5, if the distillate fuel oil used by EQUI 11 is from the same supplier and delivery as the distillate fuel oil used by EQUI 5 (two separate fuel oil storage tanks are used; one for EQUI 11 and another for EQUI 5). [Minn. R. 7007.subps. 4-5, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.8.35 Operating Hours Recordkeeping: On each day of operation, the Permittee shall record the operating hours to the nearest tenth of an hour. By the last day of each month, the Permittee shall calculate and record the operating hours for the previous month based on the daily records, and for the previous 12-month period based on the monthly records. [Minn. R. 7007.0800, subps. 4-5, Title I Condition: 40 CFR 52.21(k)(1)(i) & Minn. R. 7007.3000]

5.8.36 Hours of Operation: The Permittee shall maintain documentation on site that the unit 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. (EQUI 11 is limited to 300 hours of operation per year.). [Minn. R. 7007.0800, subps. 4-5]


5.8.38 EQUI 11 shall operate on ultra low sulfur (15 ppm) diesel fuel. [Minn. R. 7007.0800, subp. 2]

5.8.39 The Permittee shall orient STRU 18 so that it vents emissions from EQUI 11 vertically without obstruction. [Minn. R. 7007.0800, subp. 2]



5.8.40 The Permittee shall locate EQUI 11 away from fresh air intake vents. If the generator is located near a school or daycare, be aware of times and areas when and where people congregate and avoid them. [Minn. R. 7007.0800, subp. 2]


5.9.1 The combustion turbine shall demonstrate a maximum net heat rate of 7,979 Btu/kWh (HHV) while conducting net rate performance testing at base load unfired 1X1 operation. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]



5.9.4 Permitted Fuel Type: Natural gas as defined in 40 CFR Section 72.2 except total sulfur content shall not exceed 0.8 grains/100 scf and the natural gas shall be obtained from a supplier through a pipeline. [Minn. R. 7011.2300, subp. 2, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]


5.9.6 Fuel Supplier Certification: The Permittee shall obtain and maintain annual fuel supplier certification for pipeline delivery of natural gas, certifying that the sulfur content does not exceed 0.8 grains/100 scf. [Minn. R. 7007.0800, subps. 4-5, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]




5.9.10 TR NOx Emissions monitoring, reporting, and recordkeeping requirements. 1) The owners and operators and the designated representative of each TR NOx Annual source and each TR NOx Annual unit at the source shall comply with the monitoring, reporting, and recordkeeping requirements of 40 CFR Section 97.430 (general requirements, including installation, certification, and data accounting, compliance deadlines, reporting data, prohibitions, and long-term cold storage), 40



CFR Section 97.431 (initial monitoring system certification and recertification procedures), 40 CFR Section 97.432 (monitoring system out-of-control periods), 40 CFR Section 97.433 (notifications concerning monitoring), 40 CFR Section 97.434 (recordkeeping and reporting, including monitoring plans, certification applications, quarterly reports, and compliance certification), and 40 CFR Section 97.435 (petitions for alternatives to monitoring, recordkeeping, or reporting requirements). 2) The emissions data determined in accordance with 40 CFR Section 97.430 through 97.435 shall be used to calculate allocations of TR NOx Annual allowances under 40 CFR Section 97.411(a)(2) and (b) and 40 CFR Section 97.412 and to determine compliance with the TR NOx Annual emissions limitation and assurance provisions under paragraph 40 CFR Section 97.406(c) below, provided that, for each monitoring location from which mass emissions are reported, the mass emissions amount used in calculating such allocations and determining such compliance shall be the mass emissions amount for the monitoring location determined in accordance with 40 CFR Section 97.430 through 97.435 and rounded to the nearest ton, with any fraction of a ton less than 0.50 being deemed to be zero. [40 CFR 97.406(b)]

5.9.11 TR NOx Annual emissions limitation. i) As of the allowance transfer deadline (midnight of March 1 (if it is a business day), or midnight of the first business day thereafter (if March 1 is not a business day)) for a control period in a given year, the owners and operators of each TR NOx Annual source and each TR NOx Annual unit at the source shall hold, in the source's compliance account, TR NOx Annual allowances available for deduction for such control period under 40 CFR Section 97.424(a) in an amount not less than the tons of total NOx emissions for such control period from all TR NOx Annual units at the source. ii) If total NOx emissions during a control period in a given year from the TR NOx Annual units at a TR NOx Annual source are in excess of the TR NOx Annual emissions limitation set forth in 40 CFR Section 97.406(c)(1)(i) above, then: A) The owners and operators of the source and each TR NOx Annual unit at the source shall hold the TR NOx Annual allowances required for deduction under 40 CFR Section 97.424(d); and B) The owners and operators of the source and each TR NOx Annual unit at the source shall pay any fine, penalty, or assessment or comply with any other remedy imposed, for the same violations, under the Clean Air Act, and each ton of such excess emissions and each day of such control period shall constitute a separate violation of 40 CFR part 97, subpart AAAAA and the Clean Air Act. [40 CFR 97.406(c)(1)]

5.9.12 TR NOx Annual assurance provisions. i) If total NOx emissions during a control period in a given year from all TR NOx Annual units at TR NOx Annual sources in Minnesota and Indian country within the borders of Minnesota



exceed the state assurance level, then the owners and operators of such sources and units in each group of one or more sources and units having a common designated representative for such control period, where the common designated representative's share of such NOx emissions during such control period exceeds the common designated representative's assurance level for the state and such control period, shall hold (in the assurance account established for the owners and operators of such group) TR NOx Annual allowances available for deduction for such control period under 40 CFR Section 97.425(a) in an amount equal to two times the product (rounded to the nearest whole number), as determined by the Administrator in accordance with 40 CFR Section 97.425(b), of multiplying- A) The quotient of the amount by which the common designated representative's share of such NOx emissions exceeds the common designated representative's assurance level divided by the sum of the amounts, determined for all common designated representatives for such sources and units in the Minnesota and Indian country within the borders of Minnesota for such control period, by which each common designated representative's share of such NOx emissions exceeds the respective common designated representative's assurance level; and B) The amount by which total NOx emissions from all TR NOx Annual units at TR NOx Annual sources in Minnesota and Indian country within the borders of Minnesota for such control period exceed the state assurance level. ii) The owners and operators shall hold the TR NOx Annual allowances required under 40 CFR Section 97.406(c)(2)(i) above, as of midnight of November 1 (if it is a business day), or midnight of the first business day thereafter (if November 1 is not a business day), immediately after such control period. iii) Total NOx emissions from all TR NOx Annual units at TR NOx Annual sources in Minnesota and Indian country within in the borders of Minnesota during a control period in a given year exceed the state assurance level if such total NOx emissions exceed the sum, for such control period, of the state NOx Annual trading budget under 40 CFR Section 97.410(a) and the state's variability limit under 40 CFR Section 97.410(b). iv) It shall not be a violation of 40 CFR part 97, subpart AAAAA or of the Clean Air Act if total NOx emissions from all TR NOx Annual units at TR NOx Annual sources in Minnesota and Indian country within the borders of Minnesota during a control period exceed the state assurance level or if a common designated representative's share of total NOx emissions from the TR NOx Annual units at TR NOx Annual sources in the Minnesota and Indian country within the borders of Minnesota during a control period exceeds the common designated representative's assurance level. v) To the extent the owners and operators fail to hold TR NOx Annual allowances for a control period in a given year in accordance with 40 CFR Section 97.406(c)(2)(i) through (iii)



above, A. The owners and operators shall pay any fine, penalty, or assessment or comply with any other remedy imposed under the Clean Air Act; and B. Each TR NOx Annual allowance that the owners and operators fail to hold for such control period in accordance with 40 CFR Section 97.406(c)(2)(i) through (iii) above and each day of such control period shall constitute a separate violation of 40 CFR part 97, subpart AAAAA and the Clean Air Act. [40 CFR 97.406(c)(2)(i)-(v)]




5.9.16 Limited authorization. A TR NOx Annual allowance is a limited authorization to emit one ton of NOx during the control period in one year. Such authorization is limited in its use and duration as follows: i) Such authorization shall only be used in accordance with the TR NOx Annual Trading Program; and ii) Notwithstanding any other provision of 40 CFR part 97, the Administrator has the authority to terminate or limit the use and duration of such authorization to the extent the Administrator determines is necessary or appropriate to implement any provision of the Clean Air Act. [40 CFR 97.406(c)(6)]

5.9.17 Property right. A TR NOx Annual allowance does not constitute



a property right. [40 CFR 97.406(c)(7)]



5.9.20 Effect on other authorities. No provision of the TR NOx Annual Trading Program or exemption under 40 CFR Section 97.405 shall be construed as exempting or excluding the owners and operators, and the designated representative, of a TR NOx Annual source or TR NOx Annual unit from compliance with any other provision of the applicable, approved state implementation plan, a federally enforceable permit, or the Clean Air Act. [40 CFR



97.406(g)]




5.9.24 TR SO2 Group 2 emissions limitation. i) As of the allowance transfer deadline (midnight of March 1 (if it is a business day), or midnight of the first business day thereafter (if March 1 is not a business day)) for a control period in a given year, the owners and operators of each TR SO2 Group 2 source and each TR SO2 Group 2 unit at the source shall hold, in the source's compliance account, TR SO2 Group 2 allowances available for deduction for such control period under 40 CFR Section 97.724(a) in an amount not less



than the tons of total SO2 emissions for such control period from all TR SO2 Group 2 units at the source. ii) If total SO2 emissions during a control period in a given year from the TR SO2 Group 2 units at a TR SO2 Group 2 source are in excess of the TR SO2 Group 2 emissions limitation set forth in paragraph 40 CFR Section 97.706(c)(1)(i) above, then: A) The owners and operators of the source and each TR SO2 Group 2 unit at the source shall hold the TR SO2 Group 2 allowances required for deduction under 40 CFR Section 97.724(d); and B) The owners and operators of the source and each TR SO2 Group 2 unit at the source shall pay any fine, penalty, or assessment or comply with any other remedy imposed, for the same violations, under the Clean Air Act, and each ton of such excess emissions and each day of such control period shall constitute a separate violation of 40 CFR part 97, subpart DDDDD and the Clean Air Act. [40 CFR 97.706(c)(1)]

5.9.25 TR SO2 Group 2 assurance provisions. â€‹i) If total SO2 emissions during a control period in a given year from all TR SO2 Group 2 units at TR SO2 Group 2 sources in Minnesota and Indian country within the borders of Minnesota exceed the state assurance level, then the owners and operators of such sources and units in each group of one or more sources and units having a common designated representative for such control period, where the common designated representative's share of such SO2 emissions during such control period exceeds the common designated representative's assurance level for the state and such control period, shall hold (in the assurance account established for the owners and operators of such group) TR SO2 Group 2 allowances available for deduction for such control period under 40 CFR Section 97.725(a) in an amount equal to two times the product (rounded to the nearest whole number), as determined by the Administrator in accordance with 40 CFR Section 97.725(b), of multiplying- A) The quotient of the amount by which the common designated representative's share of such SO2 emissions exceeds the common designated representative's assurance level divided by the sum of the amounts, determined for all common designated representatives for such sources and units in Minnesota and Indian country within the borders of Minnesota for such control period, by which each common designated representative's share of such SO2 emissions exceeds the respective common designated representative's assurance level; and B) The amount by which total SO2 emissions from all TR SO2 Group 2 units at TR SO2 Group 2 sources in Minnesota and Indian country within the borders of Minnesota for such control period exceed the state assurance level. ii) The owners and operators shall hold the TR SO2 Group 2 allowances required under 40 CFR Section 97.706(c)(2)(i) above, as of midnight of November 1 (if it is a business day), or midnight of the first business day thereafter (if November 1 is not a business day), immediately after such control period.



iii) Total SO2 emissions from all TR SO2 Group 2 units at TR SO2 Group 2 sources in Minnesota and Indian country within the borders of Minnesota during a control period in a given year exceed the state assurance level if such total SO2 emissions exceed the sum, for such control period, of the state SO2 Group 2 trading budget under 40 CFR Section 97.710(a) and the state's variability limit under 40 CFR Section 97.710(b). iv) It shall not be a violation of 40 CFR part 97, subpart DDDDD or of the Clean Air Act if total SO2 emissions from all TR SO2 Group 2 units at TR SO2 Group 2 sources in Minnesota and Indian country within the borders of Minnesota during a control period exceed the state assurance level or if a common designated representative's share of total SO2 emissions from the TR SO2 Group 2 units at TR SO2 Group 2 sources in Minnesota and Indian country within the borders of Minnesota during a control period exceeds the common designated representative's assurance level. v) To the extent the owners and operators fail to hold TR SO2 Group 2 allowances for a control period in a given year in accordance with 40 CFR Section 97.706(c)(2)(i) through (iii) above, A.) The owners and operators shall pay any fine, penalty, or assessment or comply with any other remedy imposed under the Clean Air Act; and B.) Each TR SO2 Group 2 allowance that the owners and operators fails to hold for such control period in accordance with 40 CFR Section 97.706(c)(2)(i) through (iii) above and each day of such control period shall constitute a separate violation of 40 CFR part 97, subpart DDDDD and the Clean Air Act. [40 CFR 97.706(c)(2)(i)-(v)]


5.9.27 Vintage of allowances held for compliance. i) A TR SO2 Group 2 allowance held for compliance with the requirements under 40 CFR Section 97.706(c)(1)(i) above for a control period in a given year must be a TR SO2 Group 2 allowance that was allocated for such control period or a control period in a prior year. ii) A TR SO2 Group 2 allowance held for compliance with the requirements under 40 CFR Section 97.706(c)(1)(ii)(A) and (2)(i) through (iii) above for a control period in a given year must be a TR SO2 Group 2 allowance that was allocated for a control period in a prior year or the control period in the given



year or in the immediately following year. [40 CFR 97.706(c)(4)]




5.9.31 Additional recordkeeping and reporting requirements. 1) Unless otherwise provided, the owners and operators of each TR SO2 Group 2 source and each TR SO2 Group p2 unit at the source shall keep on site at the source each of the following documents (in hardcopy or electronic format) for a period of 5 years from the date the document is created. This period may be extended for cause, at any time before the end of 5 years, in writing by the Administrator. i) The certificate of representation under 40 CFR Section 97.716 for the designated representative for the source and each TR SO2 Group 2 unit at the source and all documents that demonstrate the truth of the statements in the certificate of representation; provided that the certificate and documents shall be retained on site at the source beyond such 5-year period until such certificate of representation and documents are superseded because of the submission of a new certificate of representation under 40 CFR Section 97.716 changing the designated representative. ii) All emissions monitoring information, in accordance with 40 CFR part 97, subpart DDDDD. iii) Copies of all reports, compliance certifications, and other submissions and all records made or required under, or to demonstrate compliance with the requirements of, the TR SO2 Group 2 Trading Program. 2) The designated representative of a TR SO2 Group 2 source and each TR SO2 Group 2 unit at the source shall make all submissions required under the TR SO2 Group 2 Trading Program, except as provided in 40 CFR Section 97.718. This requirement does not change, create an exemption from, or otherwise affect the responsible official submission



requirements under a title V operating permit program in parts 70 and 71. [40 CFR 97.706(e)]



5.9.34 Additional requirements for Combustion Turbine #1 are located at STRU 20. [Minn. R. 7007.0800, subp. 2]

EQUI 17 EU009 Duct Burners (Combustion Turbine #1)

5.10.1 Permitted Fuel Type: Natural gas as defined in 40 CFR Section 72.2, except total sulfur content shall not exceed 0.8 grains/100 scf and the natural gas shall be obtained from a supplier through a pipeline. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.10.2 Fuel Supplier Certification: The Permittee shall obtain and maintain annual fuel supplier certification for pipeline delivery of natural gas, certifying that the sulfur content does not exceed 0.8 grains/100 scf. [Minn. R. 7007.0800, subps. 4-5, Title I Condition: 40 CFR pt. 52, 21(j)(BACT) & Minn. R. 7007.3000]






5.10.6 TR NOx Emissions monitoring, reporting, and recordkeeping requirements. 1) The owners and operators and the designated representative of each TR NOx Annual source and each TR NOx Annual unit at the source shall comply with the monitoring, reporting, and recordkeeping requirements of 40 CFR Section 97.430 (general requirements, including installation, certification, and data accounting, compliance deadlines, reporting data, prohibitions, and long-term cold storage), 40 CFR Section 97.431 (initial monitoring system certification and recertification procedures), 40 CFR Section 97.432 (monitoring system out-of-control periods), 40 CFR Section 97.433 (notifications concerning monitoring), 40 CFR Section 97.434 (recordkeeping and reporting, including monitoring plans, certification applications, quarterly reports, and compliance certification), and 40 CFR Section 97.435 (petitions for alternatives to monitoring, recordkeeping, or reporting requirements). 2) The emissions data determined in accordance with 40 CFR Section 97.430 through 97.435 shall be used to calculate allocations of TR NOx Annual allowances under 40 CFR Section 97.411(a)(2) and (b) and 40 CFR Section 97.412 and to determine compliance with the TR NOx Annual emissions limitation and assurance provisions under paragraph 40 CFR Section 97.406(c) below, provided that, for each monitoring location from which mass emissions are reported, the mass emissions amount used in calculating such allocations and determining such compliance shall be the mass emissions amount for the monitoring location determined in accordance with 40 CFR Section 97.430 through 97.435 and rounded to the nearest ton, with any fraction of a ton less than 0.50 being deemed to be zero. [40 CFR 97.406(b)]

5.10.7 TR NOx Annual emissions limitation. i) As of the allowance transfer deadline (midnight of March 1 (if it is a business day), or midnight of the first business day thereafter (if March 1 is not a business day)) for a control period in a given year, the owners and operators of each TR NOx Annual source and each TR NOx Annual unit at the source shall hold, in the source's compliance account, TR NOx Annual allowances available for deduction for such control period under 40 CFR Section 97.424(a) in an amount not less than the tons of total NOx emissions for such control period from all TR NOx Annual units at the source. ii) If total NOx emissions during a control period in a given year from the TR NOx Annual units at a TR NOx Annual source are in excess of the TR NOx Annual emissions limitation set forth in 40 CFR Section 97.406(c)(1)(i) above, then: A) The owners and operators of the source and each TR NOx Annual unit at the source shall hold the TR NOx Annual allowances required for deduction under 40 CFR Section 97.424(d); and B) The owners and operators of the source and each TR NOx Annual unit at the source shall pay any fine, penalty, or assessment or comply



with any other remedy imposed, for the same violations, under the Clean Air Act, and each ton of such excess emissions and each day of such control period shall constitute a separate violation of 40 CFR part 97, subpart AAAAA and the Clean Air Act. [40 CFR 97.406(c)(1)]

5.10.8 TR NOx Annual assurance provisions. i) If total NOx emissions during a control period in a given year from all TR NOx Annual units at TR NOx Annual sources in Minnesota and Indian country within the borders of Minnesota exceed the state assurance level, then the owners and operators of such sources and units in each group of one or more sources and units having a common designated representative for such control period, where the common designated representative's share of such NOx emissions during such control period exceeds the common designated representative's assurance level for the state and such control period, shall hold (in the assurance account established for the owners and operators of such group) TR NOx Annual allowances available for deduction for such control period under 40 CFR Section 97.425(a) in an amount equal to two times the product (rounded to the nearest whole number), as determined by the Administrator in accordance with 40 CFR Section 97.425(b), of multiplying- A) The quotient of the amount by which the common designated representative's share of such NOx emissions exceeds the common designated representative's assurance level divided by the sum of the amounts, determined for all common designated representatives for such sources and units in the Minnesota and Indian country within the borders of Minnesota for such control period, by which each common designated representative's share of such NOx emissions exceeds the respective common designated representative's assurance level; and B) The amount by which total NOx emissions from all TR NOx Annual units at TR NOx Annual sources in Minnesota and Indian country within the borders of Minnesota for such control period exceed the state assurance level. ii) The owners and operators shall hold the TR NOx Annual allowances required under 40 CFR Section 97.406(c)(2)(i) above, as of midnight of November 1 (if it is a business day), or midnight of the first business day thereafter (if November 1 is not a business day), immediately after such control period. iii) Total NOx emissions from all TR NOx Annual units at TR NOx Annual sources in Minnesota and Indian country within in the borders of Minnesota during a control period in a given year exceed the state assurance level if such total NOx emissions exceed the sum, for such control period, of the state NOx Annual trading budget under 40 CFR Section 97.410(a) and the state's variability limit under 40 CFR Section 97.410(b). iv) It shall not be a violation of 40 CFR part 97, subpart AAAAA or of the Clean Air Act if total NOx emissions from all TR NOx Annual units at TR NOx Annual sources in Minnesota and Indian country within the borders of Minnesota during a



control period exceed the state assurance level or if a common designated representative's share of total NOx emissions from the TR NOx Annual units at TR NOx Annual sources in the Minnesota and Indian country within the borders of Minnesota during a control period exceeds the common designated representative's assurance level. v) To the extent the owners and operators fail to hold TR NOx Annual allowances for a control period in a given year in accordance with 40 CFR Section 97.406(c)(2)(i) through (iii) above, A. The owners and operators shall pay any fine, penalty, or assessment or comply with any other remedy imposed under the Clean Air Act; and B. Each TR NOx Annual allowance that the owners and operators fail to hold for such control period in accordance with 40 CFR Section 97.406(c)(2)(i) through (iii) above and each day of such control period shall constitute a separate violation of 40 CFR part 97, subpart AAAAA and the Clean Air Act. [40 CFR 97.406(c)(2)(i)-(v)]




5.10.12 Limited authorization. A TR NOx Annual allowance is a limited authorization to emit one ton of NOx during the control period in one year. Such authorization is limited in its use and duration as follows:



i) Such authorization shall only be used in accordance with the TR NOx Annual Trading Program; and ii) Notwithstanding any other provision of 40 CFR part 97, the Administrator has the authority to terminate or limit the use and duration of such authorization to the extent the Administrator determines is necessary or appropriate to implement any provision of the Clean Air Act. [40 CFR 97.406(c)(6)]



5.10.15 Liability. 1) Any provision of the TR NOx Annual Trading Program that applies to a TR NOx Annual source or the designated representative of a TR NOx Annual source shall also apply to the owners and operators of such source and of the TR NOx Annual unit shall also apply to the owners and operators of such unit. 2) Any provision of the TR NOx Annual Trading Program that applies to a TR NOx Annual unit or the designated representative of a TR NOx Annual unit shall also apply to the



owners and operators of such unit. [40 CFR 97.406(f)]

5.10.16 Effect on other authorities. No provision of the TR NOx Annual Trading Program or exemption under 40 CFR Section 97.405 shall be construed as exempting or excluding the owners and operators, and the designated representative, of a TR NOx Annual source or TR NOx Annual unit from compliance with any other provision of the applicable, approved state implementation plan, a federally enforceable permit, or the Clean Air Act. [40 CFR 97.406(g)]






5.10.20 TR SO2 Group 2 emissions limitation. i) As of the allowance transfer deadline (midnight of March 1 (if it is a business day), or midnight of the first business day thereafter (if March 1 is not a business day)) for a control period in a given year, the owners and operators of each TR SO2 Group 2 source and each TR SO2 Group 2 unit at the source shall hold, in the source's compliance account, TR SO2 Group 2 allowances available for deduction for such control period under 40 CFR Section 97.724(a) in an amount not less than the tons of total SO2 emissions for such control period from all TR SO2 Group 2 units at the source. ii) If total SO2 emissions during a control period in a given year from the TR SO2 Group 2 units at a TR SO2 Group 2 source are in excess of the TR SO2 Group 2 emissions limitation set forth in paragraph 40 CFR Section 97.706(c)(1)(i) above, then: A) The owners and operators of the source and each TR SO2 Group 2 unit at the source shall hold the TR SO2 Group 2 allowances required for deduction under 40 CFR Section 97.724(d); and B) The owners and operators of the source and each TR SO2 Group 2 unit at the source shall pay any fine, penalty, or assessment or comply with any other remedy imposed, for the same violations, under the Clean Air Act, and each ton of such excess emissions and each day of such control period shall constitute a separate violation of 40 CFR part 97, subpart DDDDD and the Clean Air Act. [40 CFR 97.706(c)(1)]

5.10.21 TR SO2 Group 2 assurance provisions. â€‹i) If total SO2 emissions during a control period in a given year from all TR SO2 Group 2 units at TR SO2 Group 2 sources in Minnesota and Indian country within the borders of Minnesota exceed the state assurance level, then the owners and operators of such sources and units in each group of one or more sources and units having a common designated representative for such control period, where the common designated representative's share of such SO2 emissions during such control period exceeds the common designated representative's assurance level for the state and such control period, shall hold (in the assurance account established for the owners and operators of such group) TR SO2 Group 2 allowances available for deduction for such control period under 40 CFR Section 97.725(a) in an amount equal to two times the product (rounded to the nearest whole number), as determined by the Administrator in accordance with 40 CFR Section 97.725(b), of multiplying- A) The quotient of the amount by which the common designated representative's share of such SO2 emissions exceeds the common designated representative's assurance level divided by the sum of the amounts, determined for all common designated representatives for such sources and units in Minnesota and Indian country within the borders of Minnesota for such control period, by which each common designated representative's share of such SO2 emissions exceeds the respective common designated representative's assurance



level; and B) The amount by which total SO2 emissions from all TR SO2 Group 2 units at TR SO2 Group 2 sources in Minnesota and Indian country within the borders of Minnesota for such control period exceed the state assurance level. ii) The owners and operators shall hold the TR SO2 Group 2 allowances required under 40 CFR Section 97.706(c)(2)(i) above, as of midnight of November 1 (if it is a business day), or midnight of the first business day thereafter (if November 1 is not a business day), immediately after such control period. iii) Total SO2 emissions from all TR SO2 Group 2 units at TR SO2 Group 2 sources in Minnesota and Indian country within the borders of Minnesota during a control period in a given year exceed the state assurance level if such total SO2 emissions exceed the sum, for such control period, of the state SO2 Group 2 trading budget under 40 CFR Section 97.710(a) and the state's variability limit under 40 CFR Section 97.710(b). iv) It shall not be a violation of 40 CFR part 97, subpart DDDDD or of the Clean Air Act if total SO2 emissions from all TR SO2 Group 2 units at TR SO2 Group 2 sources in Minnesota and Indian country within the borders of Minnesota during a control period exceed the state assurance level or if a common designated representative's share of total SO2 emissions from the TR SO2 Group 2 units at TR SO2 Group 2 sources in Minnesota and Indian country within the borders of Minnesota during a control period exceeds the common designated representative's assurance level. v) To the extent the owners and operators fail to hold TR SO2 Group 2 allowances for a control period in a given year in accordance with 40 CFR Section 97.706(c)(2)(i) through (iii) above, A.) The owners and operators shall pay any fine, penalty, or assessment or comply with any other remedy imposed under the Clean Air Act; and B.) Each TR SO2 Group 2 allowance that the owners and operators fails to hold for such control period in accordance with 40 CFR Section 97.706(c)(2)(i) through (iii) above and each day of such control period shall constitute a separate violation of 40 CFR part 97, subpart DDDDD and the Clean Air Act. [40 CFR 97.706(c)(2)(i)-(v)]


5.10.23 Vintage of allowances held for compliance. i) A TR SO2 Group 2 allowance held for compliance with the



requirements under 40 CFR Section 97.706(c)(1)(i) above for a control period in a given year must be a TR SO2 Group 2 allowance that was allocated for such control period or a control period in a prior year. ii) A TR SO2 Group 2 allowance held for compliance with the requirements under 40 CFR Section 97.706(c)(1)(ii)(A) and (2)(i) through (iii) above for a control period in a given year must be a TR SO2 Group 2 allowance that was allocated for a control period in a prior year or the control period in the given year or in the immediately following year. [40 CFR 97.706(c)(4)]




5.10.27 Additional recordkeeping and reporting requirements. 1) Unless otherwise provided, the owners and operators of each TR SO2 Group 2 source and each TR SO2 Group p2 unit at the source shall keep on site at the source each of the following documents (in hardcopy or electronic format) for a period of 5 years from the date the document is created. This period may be extended for cause, at any time before the end of 5 years, in writing by the Administrator. i) The certificate of representation under 40 CFR Section 97.716 for the designated representative for the source and each TR SO2 Group 2 unit at the source and all documents that demonstrate the truth of the statements in the certificate of representation; provided that the certificate and documents shall be retained on site at the source beyond such 5-year period until such certificate of representation and documents are superseded because of the submission of a new certificate of representation under 40 CFR Section 97.716 changing the designated representative. ii) All emissions monitoring information, in accordance with 40 CFR part 97, subpart DDDDD. iii) Copies of all reports, compliance certifications, and other



submissions and all records made or required under, or to demonstrate compliance with the requirements of, the TR SO2 Group 2 Trading Program. 2) The designated representative of a TR SO2 Group 2 source and each TR SO2 Group 2 unit at the source shall make all submissions required under the TR SO2 Group 2 Trading Program, except as provided in 40 CFR Section 97.718. This requirement does not change, create an exemption from, or otherwise affect the responsible official submission requirements under a title V operating permit program in parts 70 and 71. [40 CFR 97.706(e)]



5.10.30 Additional requirements for Duct Burners (Combustion Turbine #1) are located at STRU 20. [Minn. R. 7007.0800, subp. 2]

EQUI 18 EU010 Diesel Fired Emergency Generator



5.11.3 The Permittee shall limit Operating Hours <= 100 hours per year 12-month rolling sum calculated monthly by the last day of each month. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.11.4 Operating Hours Daily Recordkeeping: On each day of operation, the Permittee shall record the operating hours to the nearest tenth of an hour. [Minn. R. 7007.0800, subps. 4-5, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.11.5 Operating Hours Monthly Recordkeeping: By the 15th of each



month, the Permittee shall calculate and record the operating hours for the previous month by summing the daily operating hour records, and for the previous 12-month period by summing the previous 12 monthly records. [Minn. R. 7007.0800, subps. 4-5]

5.11.6 The Permittee shall operate EQUI 18 in a manner consistent with good energy efficiency measures according to the manufacturer's specifications to restrict GHG (greenhouse gas) emissions. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.11.7 Fuel type: No. 2 fuel oil/diesel fuel meeting the requirements of 40 CFR Section 80.510(c) only. [Minn. R. 7005.0100, subp. 35a]


5.11.9 Fuel Supplier Certification: The Permittee shall obtain and maintain a fuel supplier certification for each shipment of diesel fuel oil, certifying that the sulfur content does not exceed 0.050 percent by weight. [Minn. R. 7007.0800, subps. 4-5]

5.11.10 The Permittee shall use only ultra low sulfur (15 ppm) diesel fuel in EQUI 18. [Minn. R. 7007.0800, subp. 2]

5.11.11 The Permittee shall orient STRU 21 so that it vents emissions from EQUI 18 vertically without obstruction. [Minn. R. 7007.0800, subp. 2]

5.11.12 The Permittee shall place EQUI 18 in a location that does not affect ambient or indoor air. If the generator is located near a school or daycare, be aware of times and areas when and where people congregate and avoid them. [Minn. R. 7007.0800, subp. 2]

5.11.13 EQUI 18 is a new affected source as defined under 40 CFR pt. 63, subp. ZZZZ, and the facility is an area source as defined at 40 CFR Section 63.2, and EQUI 18 is a CI RICE with a site rating of 3352.6 brake HP (2500 kW). The Permittee shall meet the requirements of 40 CFR pt. 63, subp. ZZZZ by meeting the requirements of 40 CFR pt. 60, subp. IIII. No further requirements of 40 CFR pt. 63, subp. ZZZZ apply to EQUI 18. [40 CFR 63.6590(c), Minn. R. 7011.8150]

5.11.14 An affected source that meets any of the criteria in 40 CFR Section 63.6590(c)(1) through (7) must meet the requirements of this part by meeting the requirements of 40 CFR part 60 subpart IIII, for compression ignition engines. No further requirements apply for such engines under this part. [40 CFR 63.6590(c), Minn. R. 7011.8150]

5.11.15 The Permittee must comply with the emission standards for new nonroad CI engines in 40 CFR Section 60.4202, for all pollutants, for the same model year and maximum engine power for their 2007 model year and later emergency stationary CI ICE. [40 CFR 60.4205(b), 40 CFR 63.6590(c)(1), Minn. R. 7011.2305, Minn. R. 7011.8150]

5.11.16 The Permittee must operate and maintain stationary CI ICE that achieve the emission standards as required in 40 CFR



Sections 60.4204 and 60.4205 over the entire life of the engine. [40 CFR 60.4206, 40 CFR 63.6590(c)(1), Minn. R. 7011.2305, Minn. R. 7011.8150]

5.11.17 The Permittee must use diesel fuel that meets the requirements of 40 CFR Section 80.510(b) for nonroad diesel fuel, except that any existing diesel fuel purchased (or otherwise obtained) prior to October 1, 2010, may be used until depleted. [40 CFR 60.4207(b), 40 CFR 63.6590(c)(1), 40 CFR 80.510(b), Minn. R. 7011.2305, Minn. R. 7011.8150]

5.11.18 The Permittee must meet the monitoring requirements of this section. In addition, the Permittee must also meet the monitoring requirements specified in 40 CFR Section 60.4211. [40 CFR 60.4209, 40 CFR 63.6590(c)(1), Minn. R. 7011.2305, Minn. R. 7011.8150]

5.11.19 The Permittee must do all of the following, except as permitted under 40 CFR Section 60.4211(g): (1) Operate and maintain the stationary CI internal combustion engine and control device according to the manufacturer's emission-related written instructions; (2) Change only those emission-related settings that are permitted by the manufacturer; and (3) Meet the requirements of 40 CFR parts 89, 94 and/or 1068, as they apply to you. (c) The Permittee must comply by purchasing an engine certified to the emission standards in 40 CFR Section 60.4204(b), or 40 CFR Section 60.4205(b) or (c), as applicable, for the same model year and maximum (or in the case of fire pumps, NFPA nameplate) engine power. The engine must be installed and configured according to the manufacturer's emission-related specifications, except as permitted in 40 CFR Section 60.4211(g). (f) The Permittee must operate the emergency stationary ICE according to the requirements in 40 CFR Section 60.4211(f)(1) through (3). In order for the engine to be considered an emergency stationary ICE under this subpart, any operation other than emergency operation, maintenance and testing, emergency demand response, and operation in non-emergency situations for 50 hours per year, as described in 40 CFR Section 60.4211(f)(1) through (3), is prohibited. If the Permittee does not operate the engine according to the requirements in 40 CFR Section 60.4211(f)(1) through (3), the engine will not be considered an emergency engine under this subpart and must meet all requirements for non-emergency engines. (1) There is no time limit on the use of emergency stationary ICE in emergency situations. (2) The Permittee may operate the emergency stationary ICE for any combination of the purposes specified in 40 CFR Section 60.4211(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 Section 60.4211(f)(3) counts as part of the 100 hours per calendar year allowed by 40 CFR Section 60.4211(f)(2). (i) Emergency stationary ICE 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 the engine. The Permittee may petition the Administrator for approval of additional 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 emergency ICE beyond 100 hours per calendar year. (ii) Emergency stationary ICE may be operated for emergency demand response for periods in which the Reliability Coordinator under the North American Electric Reliability Corporation (NERC) Reliability Standard EOP-002-3, Capacity and Energy Emergencies (incorporated by reference, see 40 CFR Section 60.17), or other authorized entity as determined by the Reliability Coordinator, has declared an Energy Emergency Alert Level 2 as defined in the NERC Reliability Standard EOP-002-3. (iii) Emergency stationary ICE may be operated for periods where there is a deviation of voltage or frequency of 5 percent or greater below standard voltage or frequency. (continued below). [40 CFR 60.4211(a) - (f)(2), 40 CFR 63.6590(c)(1), Minn. R. 7011.2305, Minn. R. 7011.8150]

5.11.20 (continued from above) (3) Emergency stationary ICE may be operated for up to 50 hours per calendar year in non-emergency situations. The 50 hours of operation in non-emergency situations are counted as part of the 100 hours per calendar year for maintenance and testing and emergency demand response provided in 40 CFR Section 60.4211(f)(2). Except as provided in 40 CFR Section 60.4211(f)(3)(i), the 50 hours per calendar year for non-emergency situations cannot be used for peak shaving or non-emergency demand response, or to generate income for a facility to an electric grid or otherwise supply power as part of a financial arrangement with another entity. (i) The 50 hours per year for non-emergency situations can be used to supply power as part of a financial arrangement with another entity if all of the following conditions are met: (A) The engine is dispatched by the local balancing authority or local transmission and distribution system operator; (B) The dispatch is intended to mitigate local transmission and/or distribution limitations so as to avert potential voltage collapse or line overloads that could lead to the interruption of



power supply in a local area or region. (C) The dispatch follows reliability, emergency operation or similar protocols that follow specific NERC, regional, state, public utility commission or local standards or guidelines. (D) The power is provided only to the facility itself or to support the local transmission and distribution system. (E) The Permittee identifies and records the entity that dispatches the engine and the specific NERC, regional, state, public utility commission or local standards or guidelines that are being followed for dispatching the engine. The local balancing authority or local transmission and distribution system operator may keep these records on behalf of the engine owner or operator. [40 CFR 60.4211(f)(3), 40 CFR 63.6590(c)(1), Minn. R. 7011.2305, Minn. R. 7011.8150]

5.11.21 The Permittee is not required to submit an initial notification. Starting with the model years in 40 CFR pt. 60, subp. IIII table 5, if the emergency engine does not meet the standards applicable to non-emergency engines in the applicable model year, the Permittee must keep records of the operation of the engine in emergency and non-emergency service that are recorded through the non-resettable hour meter. The Permittee must record the time of operation of the engine and the reason the engine was in operation during that time. [40 CFR 60.4214(b), 40 CFR 63.6590(c)(1), 40 CFR pt. 60, subp. IIII(Table 5), Minn. R. 7011.2305, Minn. R. 7011.8150]

5.11.22 Except as provided in subparts B and C, the provisions of this part apply to the owner or operator of any stationary source which contains an affected facility, the construction or modification of which is commenced after the date of publication in this part of any standard (or, if earlier, the date of publication of any proposed standard) applicable to that facility. [40 CFR 60.1(a), Minn. R. 7011.0050]

5.11.23 Any new or revised standard of performance promulgated pursuant to section 111(b) of the Act shall apply to the owner or operator of any stationary source which contains an affected facility, the construction or modification of which is commenced after the date of publication in this part of such new or revised standard (or, if earlier, the date of publication of any proposed standard) applicable to that facility. [40 CFR 60.1(b), Minn. R. 7011.0050]

5.11.24 In addition to complying with the provisions of this part, the owner or operator of an affected facility may be required to obtain an operating permit issued to stationary sources by an authorized State air pollution control agency or by the Administrator of the U.S. Environmental Protection Agency (EPA) pursuant to Title V of the Clean Air Act (Act) as amended November 15, 1990 (42 U.S.C. 7661). For more information about obtaining an operating permit see 40 CFR pt. 70. [40 CFR 60.1(c), Minn. R. 7011.0050]

5.11.25 The availability to the public of information provided to, or otherwise obtained by, the Administrator under this part shall be governed by 40 CFR pt. 2. (Information submitted



voluntarily to the Administrator for the purposes of 40 CFR Sections 60.5 and 60.6 is governed by 40 CFR Sections 2.201 through 2.213 and not by 40 CFR Section 2.301.). [40 CFR 60.9]

5.11.26 The provisions of this part shall not be construed in any manner to preclude any State or political subdivision thereof from: (a) Adopting and enforcing any emission standard or limitation applicable to an affected facility, provided that such emission standard or limitation is not less stringent than the standard applicable to such facility. (b) Requiring the Permittee to obtain permits, licenses, or approvals prior to initiating construction, modification, or operation of such facility. [40 CFR 60.10]

5.11.27 No owner or operator shall build, erect, install, or use any article, machine, equipment or process, the use of which conceals an emission which would otherwise constitute a violation of an applicable standard. [40 CFR 60.12, Minn. R. 7011.0050]

5.11.28 Except as provided under 40 CFR Section 60.14(e) and (f), any physical or operational change to an existing facility which results in an increase in the emission rate to the atmosphere of any pollutant to which a standard applies shall be considered a modification within the meaning of section 111 of the Act. Upon modification, an existing facility shall become an affected facility for each pollutant to which a standard applies and for which there is an increase in the emission rate to the atmosphere. [40 CFR 60.14(a), Minn. R. 7011.0050]

5.11.29 Emission rate shall be expressed as kg/hr of any pollutant discharged into the atmosphere for which a standard is applicable. The Administrator shall use 40 CFR Section 60.14(b)(1) and (2) to determine emission rate. [40 CFR 60.14(b), Minn. R. 7011.0050]

5.11.30 The addition of an affected facility to a stationary source as an expansion to that source or as a replacement for an existing facility shall not by itself bring within the applicability of this part any other facility within that source. [40 CFR 60.14(c), Minn. R. 7011.0050]

5.11.31 The following shall not, by themselves, be considered modifications under this part: (1) Maintenance, repair, and replacement which the Administrator determines to be routine for a source category, subject to the provisions of 40 CFR Section 60.14(c) and 40 CFR Section 60.15. (2) An increase in production rate of an existing facility, if that increase can be accomplished without a capital expenditure on that facility. (3) An increase in the hours of operation. (4) Use of an alternative fuel or raw material if, prior to the date any standard under this part becomes applicable to that source type, as provided by 40 CFR Section 60.1, the existing



facility was designed to accommodate that alternative use. A facility shall be considered to be designed to accommodate an alternative fuel or raw material if that use could be accomplished under the facility's construction specifications as amended prior to the change. Conversion to coal required for energy considerations, as specified in section 111(a)(8) of the Act, shall not be considered a modification. (5) The addition or use of any system or device whose primary function is the reduction of air pollutants, except when an emission control system is removed or is replaced by a system which the Administrator determines to be less environmentally beneficial. (6) The relocation or change in ownership of an existing facility. [40 CFR 60.14(e), Minn. R. 7011.0050]

5.11.32 Special provisions set forth under an applicable subpart of this part shall supersede any conflicting provisions of this section. [40 CFR 60.14(f), Minn. R. 7011.0050]

5.11.33 Within 180 days of the completion of any physical or operational change subject to the control measures specified in 40 CFR Section 60.14(a), compliance with all applicable standards must be achieved. [40 CFR 60.14(g), Minn. R. 7011.0050]

5.11.34 No physical change, or change in the method of operation, at an existing electric utility steam generating unit shall be treated as a modification for the purposes of this section provided that such change does not increase the maximum hourly emissions of any pollutant regulated under this section above the maximum hourly emissions achievable at that unit during the 5 years prior to the change. [40 CFR 60.14(h), Minn. R. 7011.0050]

5.11.35 An existing facility, upon reconstruction, becomes an affected facility, irrespective of any change in emission rate. [40 CFR 60.15(a), Minn. R. 7011.0050]

5.11.36 Reconstruction means the replacement of components of an existing facility to such an extent that: (1) The fixed capital cost of the new components exceeds 50 percent of the fixed capital cost that would be required to construct a comparable entirely new facility, and (2) It is technologically and economically feasible to meet the applicable standards set forth in this part. [40 CFR 60.15(b), Minn. R. 7011.0050]

5.11.37 Fixed capital cost means the capital needed to provide all the depreciable components. [40 CFR 60.15(c), Minn. R. 7011.0050]

5.11.38 If a Permittee proposes to replace components, and the fixed capital cost of the new components exceeds 50 percent of the fixed capital cost that would be required to construct a comparable entirely new facility, the Permittee shall notify the Administrator of the proposed replacements. The notice must be postmarked 60 days (or as soon as practicable) before construction of the replacements is commenced and must



include the following information: (1) Name and address of the owner or operator. (2) The location of the existing facility. (3) A brief description of the existing facility and the components which are to be replaced. (4) A description of the existing air pollution control equipment and the proposed air pollution control equipment. (5) An estimate of the fixed capital cost of the replacements and of constructing a comparable entirely new facility. (6) The estimated life of the existing facility after the replacements. (7) A discussion of any economic or technical limitations the facility may have in complying with the applicable standards of performance after the proposed replacements. [40 CFR 60.15(d), Minn. R. 7011.0050]

5.11.39 The Administrator will determine, within 30 days of the receipt of the notice required by 40 CFR Section 60.15(d) and any additional information he may reasonably require, whether the proposed replacement constitutes reconstruction. [40 CFR 60.15(e), Minn. R. 7011.0050]

5.11.40 The Administrator's determination under 40 CFR Section 60.15(e) shall be based on: (1) The fixed capital cost of the replacements in comparison to the fixed capital cost that would be required to construct a comparable entirely new facility; (2) The estimated life of the facility after the replacements compared to the life of a comparable entirely new facility; (3) The extent to which the components being replaced cause or contribute to the emissions from the facility; and (4) Any economic or technical limitations on compliance with applicable standards of performance which are inherent in the proposed replacements. [40 CFR 60.15(f), Minn. R. 7011.0050]

5.11.41 Individual subparts of this part may include specific provisions which refine and delimit the concept of reconstruction set forth in this section. [40 CFR 60.15(g), Minn. R. 7011.0050]

5.11.42 If the Permittee is required to submit periodic reports under 40 CFR pt. 60, and there is an established timeline for submission of periodic reports that is consistent with the reporting frequency(ies) specified for such facility, the Permittee may change the dates by which periodic reports under 40 CFR pt. 60 shall be submitted (without changing the frequency of reporting) to be consistent with the schedule by mutual agreement between the Permittee and the State. The allowance in the previous sentence applies in each State beginning 1 year after the affected facility is required to be in compliance with the applicable subpart in 40 CFR pt. 60. Procedures governing the implementation of this provision are specified in paragraph (f) of 40 CFR Section 60.19. [40 CFR 60.19(d), Minn. R. 7011.0050]

5.11.43 If a Permittee supervises one or more stationary sources



affected by standards set under 40 CFR pt. 60 and that standards set under pts. 61, 63 or both of this chapter, the Permittee may arrange by mutual agreement between the Permittee and the Administrator (or the State with approved permit program) a common schedule on which periodic reports required by each applicable standard shall be submitted throughout the year. The allowance in the previous sentence applies in each State beginning 1 year after the affected facility is required to be in compliance with the applicable subpart in 40 CFR pt. 60, or 1 year after the stationary source is required to be in compliance with the applicable 40 CFR pt. 61 or 63 of this chapter standard, whichever is latest. Procedures governing the implementation of this provision are specified in paragraph (f) of 40 CFR Section 60.19. [40 CFR 60.19(e), Minn. R. 7011.0050]

5.11.44 Until an adjustment of a time period or postmark deadline has been approved by the Administrator under 40 CFR Section 60.19(f)(2) and (f)(3), the Permittee remains strictly subject to the requirements of 40 CFR pt. 60. A Permittee shall request the adjustment provided for in 40 CFR Section 60.19(f)(2) and (f)(3) each time he or she wishes to change an applicable time period or postmark deadline specified in 40 CFR pt. 60. (2) Notwithstanding time periods or postmark deadlines specified in this part for the submittal of information to the Administrator by a Permittee, or the review of such information by the Administrator, such time periods or deadlines may be changed by mutual agreement between the Permittee and the Administrator. A Permittee who wishes to request a change in a time period or postmark deadline for a particular requirement shall request the adjustment in writing as soon as practicable before the subject activity is required to take place. The Permittee shall include in the request whatever information he or she considers useful to convince the Administrator that an adjustment is warranted. (3) If, in the Administrator's judgment, a Permittee's request for an adjustment to a particular time period or postmark deadline is warranted, the Administrator will approve the adjustment. The Administrator will notify the Permittee in writing of approval or disapproval of the request for an adjustment within 15 calendar days of receiving sufficient information to evaluate the request. (4) If the Administrator is unable to meet a specified deadline, he or she will notify the Permittee of any significant delay and inform the Permittee of the amended schedule. [40 CFR 60.19(f), Minn. R. 7011.0050]

EQUI 19 EU011 Bath Heater

5.12.1 The Permittee shall limit Total Particulate Matter <= 0.40



pounds per million Btu heat input 3-hour average. [Minn. R. 7011.0515, subp. 1, Minn. R. 7011.0550]

5.12.2 Opacity <= 20 percent opacity; except for one six-minute period per hour of not more than 60 percent opacity. [Minn. R. 7011.0515, subp. 2]

EQUI 21 MR005 NOx CEM for CT

#1

5.13.1 NOx CEMS Daily Calibration Error (CE) Test: Conduct daily CE testing on the NOx CEMS in accordance with 40 CFR pt. 75, Appendix B. [40 CFR pt. 75, Appendix B(Sect 2.1)]

5.13.2 NOx CEMS RATA Notification: due 30 days before CEMS Relative Accuracy Test Audit (RATA). [Minn. R. 7017.1180, subp. 2]

5.13.3 NOx CEMS Relative Accuracy Test Audit (RATA): Due semiannually following certification of the equipment, i.e., once every two successive QA operating quarters (calendar quarter in which there are at least 168 unit operating hours). Conduct a RATA on all CEMS required by the Acid Rain Program, in accordance with 40 CFR pt. 75, Appendix B. Relative accuracy test audits may be performed annually (i.e., once every four successive QA operating quarters, rather than once every two successive QA operating quarters) if any of the conditions listed in 40 CFR pt. 75, Appendix B, Sections 2.3.1.2(a) through 2.3.1.2(i) are met. [40 CFR pt. 75, Appendix B (Sect 2.3.1), Minn. R. 7017.1020]


5.13.5 Installation Notification: due 60 days before installing the continuous emissions monitoring system. The notification shall include plans and drawings of the system. [Minn. R. 7017.1040, subp. 1]

5.13.6 Cylinder Gas Audit (CGA) Results Summary: due 30 days after end of each calendar quarter in which a CGA was conducted. [Minn. R. 7017.1180, subp. 1]

5.13.7 The CEMS/COMS requirements listed below outline the typical standards of 40 CFR Pt. 75. Additional monitoring requirements may also apply to the Facility based on the standard and it is the responsibility of the Facility to meet all applicable requirements. [Minn. R. 7007.subp. 4, A]

5.13.8 Emissions Monitoring: The owner or operator shall use a CEMS to measure emissions from EQUI 16. [40 CFR 75.10(a)]

5.13.9 Certification Application: The owner or operator shall apply for certification of each continuous emission or opacity monitoring system used under the Acid Rain Program. The owner or operator 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)(1), 40 CFR 75.63]

5.13.10 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 owner or operator 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)]

5.13.11 CEMS QA/QC NOx and Diluent Monitoring: The owner or operator of an affected facility shall operate, calibrate, and maintain each CEMS according to the QA/QC procedures in 40 CFR pt. 75, Appendix B as amended. [40 CFR 75.21(a)]

5.13.12 Quarterly Reports: Electronically report the data and information in 40 CFR Section 75.64 (a), (b), and (c) to the Administrator quarterly. [40 CFR 75.64]

5.13.13 Recordkeeping: The owner or operator shall maintain for each affected unit a file of all measurements, data, reports, and other information required by this part 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]


5.14.1 CEMS QA/QC Diluent Monitoring: The owner or operator of an affected facility shall operate, calibrate, and maintain each CEMS according to the QA/QC procedures in 40 CFR pt. 75, Appendix B as amended. [40 CFR 75.21(a)]

5.14.2 Relative Accuracy Test Audit (RATA) Notification: due 30 days before CO CEMS Relative Accuracy Test Audit (RATA). [Minn. R. 7017.1180, subp. 2]


5.14.4 Installation Notification: due 60 days before installing the continuous emissions monitoring system. The notification shall include plans and drawings of the system. [Minn. R. 7017.1040, subp. 1]

5.14.5 Cylinder Gas Audit (CGA) Results Summary: due 30 days after end of each calendar quarter in which a CGA was conducted. [Minn. R. 7017.1180, subp. 1]

5.14.6 The CEMS/COMS requirements listed below outline the typical standards of 40 CFR pt. 60 when combined with Minn. R. Additional monitoring requirements may also apply to the Facility based on this combination of standards and it is the



responsibility of the Facility to meet all applicable requirements. [Minn. R. 7017.1010]

5.14.7 Carbon Monoxide: Emissions Monitoring: The owner or operator shall use a CEMS to measure emissions from EQUI 16. [40 CFR pt. 60, subp. KKKK, Minn. R. 7017.1010, subp 1]

5.14.8 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. [40 CFR 60.7(a)(5), Minn. R. 7017.1060, subp. 1-3, Minn. R. 7017.1080, subp. 1-4]

5.14.9 Continuous Operation: CEMS must be operated and data recorded during all periods of emission unit operation including periods of emission unit start-up, shutdown, or malfunction except for periods of acceptable monitor downtime. This requirement applies whether or not a numerical emission limit applies during these periods. A CEMS must not be bypassed except in emergencies where failure to bypass would endanger human health, safety, or plant equipment. [40 CFR 60.13(e), Minn. R. 7017.1090]

5.14.10 QA Plan: Develop and implement a written quality assurance plan that covers each CEMS. The plan shall be on site and available for inspection within 30 days after monitor certification. The plan shall contain all of the information required by 40 CFR Part 60, Appendix F, Section 3. The plan shall include the manufacturer's spare parts list for each CEMS and require that those parts be kept at the facility unless the Commissioner gives written approval to exclude specific spare parts from the list. [40 CFR pt. 60, Appendix F, 3, Minn. R. 7017.1170, subp. 2]

5.14.11 CEMS QA/QC: The owner or operator of an affected facility is subject to the performance specifications listed in 40 CFR pt. 60, Appendix B and shall operate, calibrate, and maintain each CEMS according to the QA/QC procedures in 40 CFR pt. 60, Appendix F as amended and maintain a written QA/QC program available in a form suitable for inspection. [40 CFR 60.13(a), 40 CFR pt. 60, Appendix F]

5.14.12 CEMS Daily Calibration Drift Test: Check the zero (low level value between 0 and 20 percent of span value) and span (50 to 100 percent of span value) calibration drifts at least once daily. The zero and span must, at a minimum, be adjusted whenever the drift exceeds two times the limit specified in 40 CFR pt. 60, Appendix B. 40 CFR pt. 60, Appendix F, Section 4.3.1 shall be used to determine out-of-control periods for CEMS. [40 CFR 60.13(d)(1), 40 CFR pt. 60, Appendix F, 4.1, Minn. R. 7017.1170, subp. 3]

5.14.13 Recordkeeping: The owner or operator must retain records of all CEMS monitoring data and support information for a period



of five years from the date of the monitoring sample, measurement or report. Records shall be kept at the source. [40 CFR 60.7(f), Minn. R. 7017.1130]

5.14.14 CEMS Certification/Recertification Test: due 90 days after the first excess emissions report required for the CEMS or any change which invalidates the monitor's certification status as outlined in Minn. R. 7017.1050, subp. 2. [40 CFR 60.13(b)]

EQUI 23 Diesel Fired Emergency Generator Tank

5.15.1 The Permittee shall install a fixed roof tank. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.15.2 The Permittee shall maintain the tank in good working condition according to the operation and maintenance (O&M) plan. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.15.3 The Permittee shall equip the storage vessel with a permanent submerged fill pipe. [Minn. R. 7011.1505, subp. 3.B]

EQUI 24 Natural Gas Condensate Tank - Plant

5.16.1 The Permittee shall maintain the tank in good working condition according to the operation and maintenance (O&M) plan. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.16.2 The Permittee shall equip the storage vessel with a permanent submerged fill pipe. [Minn. R. 7011.1505, subp. 3.B]

FUGI 1 FS001 Cooling Tower 5.17.1 The Permittee shall control PM, PM10 and PM2.5 emissions by

installing, operating, and maintaining a mist eliminator with a drift rate designed not to exceed 0.0005%. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.17.2 Total Particulate Matter <= 0.020 grains per dry standard cubic foot. [Minn. R. 7011.0735, Table 2]

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

5.17.4 The Permittee shall maintain documentation of manufacturer's guarantee that the mist eliminator meets the design drift rate of 0.0005%. [Minn. R. 7007.0800, subp. 2]

FUGI 2 FS002 Natural Gas

Fugitives

5.18.1 The Permittee shall conduct audio/visual/olfactory (AVO) inspections each calendar quarter for natural gas piping components to detect leaks of natural gas. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.18.2 The Permittee shall keep records of the quarterly AVO leak inspections on natural gas piping components. [Minn. R.



7007.0800, subp. 5, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

FUGI 3 FS003 Breaker Fugitives

5.19.1 The Permittee shall use state-of-the-art enclosed-pressure sulfur hexafluoride (SF6) circuit breakers with leak detection for the breakers associated with EQUI 16. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.19.2 At least once per calendar month, the Permittee shall inspect the pressure and record the results of the inspection. [Title I Condition: 40 CFR pt. 52, 21(j)(BACT) & Minn. R. 7007.3000]

5.19.3 Corrective Actions: The Permittee shall take corrective action as soon as possible if the pressure of the breakers is found to be outside the manufacturer's recommended range during the monthly inspection. The Permittee shall keep a record of the type and date of any corrective action taken for FUGI 3. [Minn. R. 7007.0800, subp. 2]

STRU 14 SV002 Combustion

Turbine #2 & Duct Burners #2 Stack

5.20.1 The Permittee shall operate the combustion turbine generator/duct burner (CTG/DB; EQUI 5/EQUI 6) in a manner consistent with good combustion practices to restrict emissions of PM, PM10, NOx, CO, and VOC. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.2 Operating Mode: Normal operating mode is all operation of EQUI 5 at 60% or greater of the CTG maximum potential load based on ambient conditions at the time of operation when combusting natural gas or distillate fuel oil. Limits apply whether or not the duct burners are operating. For CO limit applicability, full load is all operation at 90% or greater of rated capacity for the ambient conditions, and less than full load is all operation greater than or equal to 60% load and less than 90% of rated capacity for the ambient conditions. The CEMS data acquisition and handling system monitors EQUI 5 load (using a CTG gross megawatt signal provided by the CTG control system (not including steam turbine electrical output)) and indicates whether EQUI 5 is operating in normal mode or startup/shutdown mode. The percent load signal is also used by the CEMS to determine whether emissions data is categorized as normal emissions data or startup/shutdown emissions data. The signal is further used to categorize normal operating hours in the 60% to less than 90% load range, and normal operating hours at or above 90% load, for HAPs calculation and CO limit applicability purposes. [Minn. R. 7007.0800, subp. 2]

5.20.3 The Permittee shall limit Nitrogen Oxides <= 3.0 parts per



million 3-hour rolling average by volume on a dry basis corrected to 15% O2 when EQUI 5 combusts natural gas. This limit does not apply during startup, shutdown, or malfunction. [40 CFR 60.332(a)(1), Minn. R. 7011.2350, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(1)(i) & Minn. R. 7007.3000]

5.20.4 The Permittee shall limit Nitrogen Oxides <= 5.5 parts per million 3-hour rolling average by volume on a dry basis corrected to 15% O2 when EQUI 5 combusts distillate fuel oil. This limit does not apply during startup, shutdown, or malfunction. [40 CFR 60.332(a)(1), Minn. R. 7011.2350, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(1)(i) & Minn. R. 7007.3000]

5.20.5 The Permittee shall limit Carbon Monoxide <= 4.0 parts per million 3-hour rolling average by volume on a dry basis corrected to 15% O2. This limit applies at all times when EQUI 5 combusts natural gas and operates at full load. This limit does not apply during startup, shutdown, or malfunction. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.6 The Permittee shall limit Carbon Monoxide <= 4.7 parts per million 3-hour rolling average by volume on a dry basis corrected to 15% O2. This limit applies at all times when EQUI 5 combusts natural gas and operates at less than full load. This limit does not apply during startup, shutdown, or malfunction. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.7 The Permittee shall limit Carbon Monoxide <= 4.8 parts per million 3-hour rolling average by volume on a dry basis corrected to 15% O2 when EQUI 5 combusts distillate fuel oil and operates at full load. This limit does not apply during startup, shutdown, or malfunction. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.8 The Permittee shall limit Carbon Monoxide <= 10.2 parts per million 3-hour rolling average by volume on a dry basis corrected to 15% O2 when EQUI 5 combusts distillate fuel oil and operates at less than full load. This limit does not apply during startup, shutdown, or malfunction. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.9 The Permittee shall limit Volatile Organic Compounds <= 3.4 parts per million 3-hour block average by volume on a dry basis corrected to 15% O2 when EQUI 5 combusts natural gas. This limit applies at all times except during startup, shutdown, or malfunction. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.10 The Permittee shall limit Volatile Organic Compounds <= 7.1 parts per million 3-hour block average by volume on a dry basis corrected to 15% O2 when EQUI 5 combusts distillate fuel oil. This limit applies at all times except during startup, shutdown, or malfunction. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.11 The Permittee shall limit Total Particulate Matter <= 0.009 pounds per million Btu heat input 3-hour block average and not to exceed 22.0 lb/hr, also on a 3-hour block average, when



combusting natural gas in EQUI 5. This limit applies at all times including during startup, shutdown, or malfunction. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.12 The Permittee shall limit Total Particulate Matter <= 0.057 pounds per million Btu heat input 3-hour block average and not to exceed 72.8 lb/hr, also on a 3-hour block average, when combusting distillate fuel oil in EQUI 5. This limit applies at all times including during startup, shutdown, or malfunction. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.13 The Permittee shall limit PM < 10 micron <= 0.009 pounds per million Btu heat input 3-hour block average and not to exceed 22.0 lb/hr, also on a 3-hour block average, when combusting natural gas in EQUI 5. This limit applies at all times including during startup, shutdown, or malfunction. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.14 The Permittee shall limit PM < 10 micron <= 0.057 pounds per million Btu heat input 3-hour block average and not to exceed 72.8 lb/hr, also on a 3-hour block average, when combusting distillate fuel oil in EQUI 5. This limit applies at all times including during startup, shutdown, or malfunction. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.15 The Permittee shall limit PM < 2.5 micron <= 0.009 pounds per million Btu heat input 3-hour block average and not to exceed 22.0 lb/hr, also on a 3-hour block average, when combusting natural gas in EQUI 5. This limit applies at all times including during startup, shutdown, or malfunction. [Minn. R. 7007.0800, subp. 2]

5.20.16 The Permittee shall limit PM < 2.5 micron <= 0.057 pounds per million Btu heat input 3-hour block average and not to exceed 72.8 lb/hr, also on a 3-hour block average, when combusting distillate fuel oil in EQUI 5. This limit applies at all times including during startup, shutdown, or malfunction. [Minn. R. 7007.0800, subp. 2]

5.20.17 The Permittee shall limit Sulfur Dioxide <= 0.8 grains of sulfur/100 standard cubic feet of natural gas on a calendar year average. This limit applies at all times including startup, shutdown, and malfunction. This limit is equivalent to 0.0022409 lb SO2/mmBtu at 1020 Btu/scf. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.18 The Permittee shall limit Sulfur Content of Fuel <= 0.05 percent by weight for No. 2 distillate fuel oil. This limit applies at all times including startup, shutdown, and malfunction. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.19 Startup and Shutdown Operating Mode is all operation of EQUI 5 at less than 60 percent of the CTG maximum potential load based on ambient conditions at the time of operation when combusting natural gas or distillate fuel oil. Cold startup is when the Combustion Turbine #2 steam turbine was last online more than 48 hours prior to the startup. Warm startup is any startup that occurs when the steam turbine was last online no more than 48 hours prior to the startup. The



steam turbine is online when any steam is fed to the steam turbine. For distillate fuel oil startup, EQUI 5 initially combusts natural gas and then switches to distillate fuel oil during the startup process. For distillate fuel oil shutdown, EQUI 5 switches from distillate fuel oil to natural gas during the shutdown process. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.20 EQUI 5 Startup, Shutdown, and Malfunction: The terms "startup", "shutdown", and "malfunction" shall have the same meanings as defined in 40 CFR Section 60.2. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.21 The Permittee shall restrict startup and shutdown operation for the CTG/DB (EQUI 5/EQUI 6) to the shortest time period possible to restrict emissions of PM, PM10, NOx, CO, and VOC. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.22 Control Equipment Operation During Startup and Shutdown: Operation of TREA 4, TREA 5, and TREA 6, and TREA 9 is not required during EQUI 5 startup. During shutdown, control equipment operation shall continue as long as is physically possible. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.23 The Permittee shall limit Nitrogen Oxides <= 7.44 tons per year 12-month rolling sum during cold startups on natural gas. NOx is limited to 323.5 lbs per cold startup event on natural gas. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.24 The Permittee shall limit Nitrogen Oxides <= 1.38 tons per year 12-month rolling sum during cold startups on distillate fuel oil. NOx is limited to 459.3 lbs per cold startup event on distillate fuel oil. Emissions from natural gas combustion that occur before the switch to distillate fuel oil that is part of the distillate fuel oil startup process are included in the emissions subject to this limit. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.25 The Permittee shall limit Nitrogen Oxides <= 13.64 tons per year 12-month rolling sum during warm startups on natural gas. NOx is limited to 148.3 lbs per warm startup event on natural gas. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.26 The Permittee shall limit Nitrogen Oxides <= 1.69 tons per year 12-month rolling sum during warm startups on distillate fuel oil. NOx is limited to 140.7 lbs per warm startup event on distillate fuel oil. Emissions from natural gas combustion that occur before the switch to distillate fuel oil that is part of the distillate fuel oil startup process are included in the emissions subject to this limit. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.27 The Permittee shall limit Nitrogen Oxides <= 0.50 tons per year



12-month rolling sum during shutdown of equipment while firing natural gas. NOx is limited to 4.4 lbs per shutdown event while firing natural gas. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.28 The Permittee shall limit Nitrogen Oxides <= 0.25 tons per year 12-month rolling sum during shutdown of equipment while firing distillate fuel oil. NOx is limited to 16.8 lbs per shutdown event while firing distillate fuel oil. Emissions from natural gas combustion that occur after the switch from distillate fuel oil to natural gas as part of the distillate fuel oil shutdown process are included in the emissions subject to this limit. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.29 The Permittee shall limit Carbon Monoxide <= 123.94 tons per year 12-month rolling sum during cold startups on natural gas. CO is limited to 5387.6 lbs per cold startup event on natural gas. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.30 The Permittee shall limit Carbon Monoxide <= 4.49 tons per year 12-month rolling sum during cold startups on distillate fuel oil. CO is limited to 1498.2 lbs per cold startup event on distillate fuel oil. Emissions from natural gas combustion that occur before the switch to distillate fuel oil that is part of the distillate fuel oil startup process are included in the emissions subject to this limit. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.31 The Permittee shall limit Carbon Monoxide <= 282.31 tons per year 12-month rolling sum during warm startups on natural gas. CO is limited to 3068.6 lbs per warm startup event on natural gas. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.32 The Permittee shall limit Carbon Monoxide <= 6.55 tons per year 12-month rolling sum during warm startups on distillate fuel oil. CO is limited to 545.9 lbs per warm startup event on distillate fuel oil. Emissions from natural gas combustion that occur before the switch to distillate fuel oil that is part of the distillate fuel oil startup process are included in the emissions subject to this limit. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.33 The Permittee shall limit Carbon Monoxide <= 5.39 tons per year 12-month rolling sum during shutdown of equipment while firing natural gas. CO is limited to 46.8 lbs per shutdown event while firing natural gas. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.34 The Permittee shall limit Carbon Monoxide <= 4.64 tons per year 12-month rolling sum during shutdown of equipment while firing distillate fuel oil. CO is limited to 309.3 lbs per



shutdown event while firing distillate fuel oil. Emissions from natural gas combustion that occur after the switch from distillate fuel oil to natural gas as part of the distillate fuel oil shutdown process are included in the emissions subject to this limit. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.35 The Permittee shall limit Volatile Organic Compounds <= 61.96 tons per year 12-month rolling sum during cold startups on natural gas only. VOC is limited to 2693.8 lbs per cold startup event on natural gas only. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.36 The Permittee shall limit Volatile Organic Compounds <= 2.25 tons per year 12-month rolling sum during cold startups on distillate fuel oil. VOC is limited to 749.1 lbs per cold startup event on distillate fuel oil. Emissions from natural gas combustion that occur before the switch to distillate fuel oil that is part of the distillate fuel oil startup process are included in the emissions subject to this limit. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.37 The Permittee shall limit Volatile Organic Compounds <= 141.15 tons per year 12-month rolling sum during warm startups on natural gas. VOC is limited to 1534.3 lbs per warm startup event on natural gas. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.38 The Permittee shall limit Volatile Organic Compounds <= 3.28 tons per year 12-month rolling sum during warm startups on distillate fuel oil. VOC is limited to 272.9 lbs per warm startup event on distillate fuel oil. Emissions from natural gas combustion that occur before the switch to distillate fuel oil that is part of the distillate fuel oil startup process are included in the emissions subject to this limit. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.39 The Permittee shall limit Volatile Organic Compounds <= 2.69 tons per year 12-month rolling sum during shutdown of equipment while firing natural gas. VOC is limited to 23.4 lbs per shutdown event while firing natural gas. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.40 The Permittee shall limit Volatile Organic Compounds <= 2.32 tons per year 12-month rolling sum during shutdown of equipment while firing distillate fuel oil. VOC is limited to 154.7 lbs per shutdown event while firing distillate fuel oil. Emissions from natural gas combustion that occur after the switch from distillate fuel oil to natural gas as part of the distillate fuel oil shutdown process are included in the emissions subject to this limit. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]



5.20.41 HAP Emissions Monitoring: The Permittee shall determine STRU 14 formaldehyde, n-hexane, other single HAPs, and total HAP emissions using daily heat input records, daily operating hours, and applicable emission factors as specified in this permit. [Minn. R. 7007.0800, subp. 4, Minn. R. 7011.7000, Title I Condition: Avoid major source under 40 CFR 63.2]

5.20.42 Daily Heat Input Monitoring: Once each calendar day, the Permittee shall calculate and record total EQUI 5 heat input (in million Btus) for each of the three defined EQUI 5 operating levels (<60% load, 60% - <90% load, and 90% or greater load) during the previous operating day. If EQUI 6 is operated, the Permittee shall calculate and separately record EQUI 6 heat input (in million Btus) for the previous operating day. EQUI 5 operating load is determined on an hourly basis according to the CTG operating capacity for the ambient conditions at the time of operation. [Minn. R. 7007.0800, subp. 4, Minn. R. 7011.7000, Title I Condition: Avoid major source under 40 CFR 63.2]

5.20.43 Determination of Formaldehyde and n-Hexane Emission Factors For Emission Calculations: 1. The Permittee shall determine the load-dependent formaldehyde emission factors for calculating formaldehyde emissions from combusting natural gas (NG) using the results from the most recent MPCA-approved and reviewed stack test as follows: a. The NG formaldehyde factor for determining emissions from operation at less than 60 percent load shall be the average of three test runs, or the maximum one hour test run as allowed by this permit, at 15 to 30 percent load; b. The NG formaldehyde factor for determining emissions from operation at 60 to less than 90 percent load shall be the average of three test runs, or the maximum one hour test run as allowed by this permit, at 60 to 70 percent load; c. The NG formaldehyde factor for determining emissions from operation equal to or greater than 90 percent load (with or without EQUI 6 operating) shall be the average of three test runs, or the maximum one hour test run as allowed by this permit, at 90 to 100 percent load (baseload with EQUI 6 operating). 2. The NG n-hexane emission factor is the factor determined while combusting NG at 90 to 100 percent load (baseload with EQUI 6 operating) from the most recent MPCA-approved and reviewed stack test. The Permittee shall use this n-hexane emission factor for calculating n-hexane emissions from combusting NG at all loads. NG formaldehyde and n-hexane emission factors are revised according to the requirements under 'Protocol for Re-Setting



Formaldehyde and n-Hexane Emission Factors' in this permit under Subject Item STRU 14. 3. The distillate fuel oil (FO) formaldehyde emission factor and the FO n-hexane emission factor were determined from the 2011 MPCA-approved and reviewed FO formaldehyde and n-hexane stack tests. The Permittee shall use the lb/hr formaldehyde emission factor specified in this permit for calculating FO formaldehyde emissions at all loads, and shall use the lb/hr n-hexane emission factor specified in this permit for calculating FO n-hexane emissions at all loads. [Minn. R. 7007.0800, subp. 4]

5.20.44 Monthly HAPs Emissions Monitoring and Recordkeeping: By the last day of each month, the Permittee shall calculate and record monthly STRU 14 formaldehyde, n-hexane, and total HAP emissions for the previous calendar month. NG HAP Emissions: Formaldehyde and n-hexane emissions from NG combustion are determined using daily EQUI 5 and EQUI 6 heat input data and the applicable lb/mmBtu emission factor. For all other single HAPs from NG combustion, EQUI 5 and EQUI 6 single HAP emissions are determined for each emission unit using each unit's daily heat input records and applicable AP-42 emission factor. FO HAP Emissions: Formaldehyde and n-hexane emissions from FO combustion are determined using daily EQUI 5 FO operating hours records and the applicable lb/hr emission factor. For all other single HAPs from EQUI 5 FO combustion, EQUI 5 single HAP emissions are determined using daily EQUI 5 FO heat input records and the applicable AP-42 emission factor. If EQUI 6 operates when EQUI 5 combusts FO, all EQUI 6 single HAP emissions (except formaldehyde and n-hexane) are determined using EQUI 6 daily heat input records and the applicable AP-42 chapter emission factor. Total HAP emissions are determined by summing all individual HAPs data for the previous calendar month. Applicable emission factors are as follows: 1. The NG lb/mmBtu formaldehyde and n-hexane emission factors determined during the most recent MPCA-approved and reviewed stack test (September 2011). a. The NG formaldehyde factors for EQUI 5 or EQUI 5/EQUI 6 based on the average of the three test runs from the most recent test are: i. 0.00215 lb/mmBtu for less than 60% load; ii. 0.00122 lb/mmBtu for 60% to less than 90% load; iii. 0.00061 lb/mmBtu for 90% or greater load regardless if



EQUI 6 is operating. b. The NG n-hexane factor for EQUI 5 or EQUI 5/EQUI 6 from the most recent test is 0.00034 lb/mmBtu for all operating loads. 2. The EQUI 5 formaldehyde factor for FO combustion (regardless if EQUI 6 is operating) is 2.28 lb/hr for all operating loads. 3. The EQUI 5 n-hexane factor for FO combustion (regardless if EQUI 6 is operating) is 0.042 lb/hr for all operating loads. 4. The EQUI 5 factor for all other single HAPs for FO combustion is the applicable emission factor from the current version of AP-42 ch. 3.1 for EQUI 5, and AP-42 ch. 1.4 for EQUI 6 (if operated). 5. Notwithstanding item 1 above, upon issuance of this permit the Permittee has the option to use the maximum one-hour formaldehyde emission rate of the three one-hour test runs while combusting NG (instead of the average of the three test runs) determined during the most recent MPCA-approved and reviewed stack test for each of the three tested operating loads for calculating formaldehyde emissions, if the Permittee prefers to test for the multi-load NG formaldehyde emission factors at 60-month intervals. This requirement may be implemented by the Permittee if the multi-load NG formaldehyde test frequency would otherwise be at an interval more frequent than 60 months based on the most current MPCA-approved and reviewed multi-load NG formaldehyde stack test results and MPCA emission factor stack test frequency guidance. The maximum one-hour NG formaldehyde factors for EQUI 5 from the most recent MPCA-approved and reviewed stack test (September 2011) are: a. 0.00279 lb/mmBtu for less than 60% load; b. 0.00151 lb/mmBtu for 60% to less than 90% load; c. 0.00105 lb/mmBtu for 90% or greater load regardless if EQUI 6 is operating. See COMG 5 for Formaldehyde, n-Hexane and HAPs Total limits. [Minn. R. 7007.0800, subp. 4]

5.20.45 See EQUI 3 for additional NOx CEMS requirements and EQUI 4 for additional CO CEMS requirements. [Minn. R. 7007.0800, subp. 2]

5.20.46 Emissions Monitoring: The Permittee shall measure or calculate SO2, NOx, and CO2 emission rates in accordance with 40 CFR pt. 75. [40 CFR 75.10, Minn. R. 7017.1020]

5.20.47 Emissions Monitoring: The Permittee shall use a Continuous



Emissions Monitoring System (CEMS) to measure NOx emissions, and measure or calculate SO2 and CO2 in accordance with 40 CFR pt. 75 for STRU 14. The Permittee shall measure NOx emissions in ppmvd corrected to 15% oxygen and automatically calculate and record the 3-hour average NOx emission rate. NOx ppmvd emission data shall also be converted to lb/mmBtu as required by 40 CFR pt. 75. [40 CFR 75.10, Minn. R. 7017.1006, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.48 Emissions Monitoring: The Permittee shall use a CEMS to measure CO emissions in ppmvd corrected to 15% oxygen. The Permittee shall automatically calculate and record the 3-hour average CO emission rate. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.20.49 Operating Load and Operating Conditions Monitoring - The Permittee shall: 1. Continuously monitor, determine, and record the hourly heat input rate (mmBtu/hr) for EQUI 5/EQUI 6 using the methods specified at 40 CFR pt. 75, Appendix D Section 3.4; 2. Monitor and record the time and duration of each startup, shutdown, and malfunction; 3. Record the start and stop time of each steam turbine-generator on-line and off-line period. 4. Monitor and record the percent operating load (using the combustion turbine automated control system and the CEMS data aquisition and handling system). [40 CFR 75.10, Minn. R. 7007.0800, subp. 4, Minn. R. 7011.7000, Minn. R. 7017.1006, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000, Title I Condition: Avoid major source under 40 CFR 63.2]

5.20.50 NOx CEMS Quality Assurance/Quality Control (QA/QC): The Permittee shall operate, calibrate, and maintain the NOx CEMS according to the QA/QC procedure in 40 CFR pt. 75, Appendix B, as amended. [40 CFR 75.21]

5.20.51 NOx CEMS and CO CEMS Continuous Operation: The NOx CEMS and CO CEMS must be operated and data recorded during all periods of emission unit operation including periods of emission unit start-up, shutdown, or malfunction except for periods of acceptable monitor downtime. This requirement applies whether or not a numerical emission limit applies during these periods. The CEMS must not be bypassed except in emergencies where failure to bypass would endanger human health, safety, or plant equipment. Acceptable CEM downtime includes reasonable periods as listed in items A, B, C and D of Minn. R. 7017.1090, subp. 2. [Minn. R. 7017.1090, subp. 1]

5.20.52 NOx and CO CAM Requirements: The Permittee shall use the NOx CEMS and CO CEMS to satisfy the requirements of 40 CFR pt. 64. [40 CFR 64.3(d), Minn. R. 7017.0200]

5.20.53 VOC CAM Requirements: The Permittee shall use the CO CEMS for VOC compliance assurance monitoring. Compliance with



the CO limit indicated by the CO CEMS assures that VOC emissions are in compliance with the VOC limit. The Permittee shall demonstrate this correlation by recording and comparing CO CEMS emissions data during STRU 14 VOC performance testing, with results of the VOC testing. The correlation shall be valid only if testing demonstrates that VOC emissions comply with the applicable VOC limit at the same time that CO emissions (measured by the CO CEMS) comply with the applicable CO limit, and the CO CEMS certification testing has been satisfactorily completed. [40 CFR 64.3(a), 40 CFR 64.6(b), Minn. R. 7017.0200]

5.20.54 Documentation of Need for Improved VOC Monitoring: If the Permittee fails to achieve compliance with the VOC emission limit when the CO CEMS did not provide an indication of a VOC emissions excursion or exceedance while the CO CEMS provided valid CO emissions data, or the results of VOC performance testing document a need to modify the existing CO indicator of VOC emissions compliance, the Permittee shall promptly notify the MPCA and, if necessary, submit a permit amendment application to address the necessary monitoring changes. [40 CFR 64.7(e), Minn. R. 7017.0200]

5.20.55 Recordkeeping: The Permittee must retain records of all CEMS monitoring data and support information for a period of five years from the date of the monitoring sample, measurement or report. Records shall be kept at the source. [40 CFR 75.57, Minn. R. 7017.1130]

5.20.56 NG Formaldehyde Testing Frequency Plan: The Permittee may submit a Testing Frequency Plan (TFP) after any formaldehyde emission factor test in order to reduce test frequency, based on the MPCA emission factor test frequency guidance, and the most recent NG formaldehyde test results. Any revision to test frequency through submittal of a TFP does not take effect until the test frequency is incorporated into this permit through a permit amendment. Notwithstanding other STRU 14 testing requirements in this permit that allow formaldehyde testing at 60-month intervals, test frequency may only be reduced through the submittal of a TFP if current test results show formaldehyde emission factor variability is less than or equal to 40% of the previous formaldehyde test at the comparable CTG operating level. As described in the MPCA emission factor test frequency guidance, test frequency may be relaxed to once every 36 months if emission factor variability is between 10% through 40% of the previous test result for the comparable CTG operating level. Test frequency may be relaxed to once every 60 months if emission factor variability is less than 10% of the previous formaldehyde test at the comparable CTG operating level. [Minn. R. 7017.2020, subp. 1]

5.20.57 Protocol for Re-Setting Emission Factors Used For Calculating Formaldehyde and n-Hexane Emissions From NG Combustion: The Permittee shall conduct performance testing under



conditions that produce: 1. The maximum formaldehyde emission rate for each of the three operating ranges (<60%, 60% - <90%, and 90% or greater load (also referred to as 'full load')); and, 2. The maximum n-hexane emission rate at 90% or greater load. The Permittee shall use U.S. EPA Reference Methods 323 and 18 to measure formaldehyde and n-hexane emissions, respectively, as required elsewhere in this permit. The Permittee shall report each test result as a lb/mmBtu emission factor in the performance test report required by Minn. R. 7017.2035, subp. 1. The emission factors for calculating formaldehyde emissions at each of the three operating ranges, and n-hexane emissions at full load, shall be re-set to the 3-hour average emission rate in lb/mmBtu, measured during the most recent MPCA-approved applicable emission factor performance. Notwithstanding the previous paragraph and as allowed elsewhere in Subject Item STRU 14 of this permit, if the Permittee elects to reduce formaldehyde testing frequency while combusting NG from once every 30 months to once every 60 months for all three operating load ranges by using the highest one-hour test run for each operating load range, the formaldehyde emission factor shall be reset to the maximum one-hour test value from the three one-hour test runs for each of the three operating load range (<60%, 60% - <90%, and 90% or greater load) tests. The new emission factors (for calculating formaldehyde and n-hexane emissions) determined using this Protocol shall be effective upon receipt of the Notice of Compliance (NOC) letter that approves the test results and shall be incorporated into the permit during the next permit amendment. [Minn. R. 7011.7000, Title I Condition: Avoid major source under 40 CFR 63.2]

5.20.58 Notwithstanding the Protocol detailed above, the MPCA reserves the right to set operational limits and requirements as allowed under Minn. R. 7017.2025. If the MPCA sets limits, the new limits shall be implemented upon receipt of the NOC letter that notifies the Permittee of preliminary approval. The limits set according to Minn. R. 7017.2025 are final upon issuance of a permit amendment incorporating the change. [Minn. R. 7017.2025]

5.20.59 The Permittee must apply for and obtain a major permit amendment if the Permittee wishes to deviate from the Protocol for Re-Setting Emission Factors Used For Calculating Formaldehyde and n-Hexane Emissions From Natural Gas



Combustion established by this permit. [Minn. R. 7007.1500, subp. 1]

5.20.60 Additional requirements for Combustion Turbine #2 are located at EQUI 5. Additional requirements for Duct Burner (Combustion Turbine #2) are located at EQUI 6. [Minn. R. 7007.0800, subp. 2]

STRU 20 SV007 Combustion Turbine #1 & Duct Burners #1 Stack

5.21.1 The Permittee shall operate the combustion turbine generator/duct burner (CTG/DB; EQUI 16/EQUI 17) in a manner consistent with good combustion practices to restrict emissions of PM, PM10, NOx, CO, and VOC. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.21.2 Operating Mode: Normal operating mode is all operation of EQUI 16 at 60% or greater of the CTG maximum potential load based on ambient conditions at the time of operation when combusting natural gas. Limits apply whether or not the duct burners are operating. For CO limit applicability, full load is all operation at 90% or greater of rated capacity for the ambient conditions, and less than full load is all operation greater than or equal to 60% load and less than 90% of rated capacity for the ambient conditions. The CEMS data acquisition and handling system monitors EQUI 16 load (using a CTG gross megawatt signal provided by the CTG control system (not including steam turbine electrical output)) and indicates whether EQUI 16 is operating in normal mode or startup/shutdown mode. The percent load signal is also used by the CEMS to determine whether emissions data is categorized as normal emissions data or startup/shutdown emissions data. The signal is further used to categorize normal operating hours in the 60% to less than 90% load range, and normal operating hours at or above 90% load, for HAPs calculation and CO limit applicability purposes. [Minn. R. 7007.0800, subp. 2]

5.21.3 The shakedown period for EQUI 16 is defined as the period of time commencing on the date of initial startup and terminating on the earlier of the following three dates: 1. 180 days after initial startup of EQUI 16, or 2. 60 days after achieving maximum production of EQUI 16, or 3. Submittal of successful compliance test and CEMS certification reports for EQUI 16. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.21.4 The Permittee shall limit Nitrogen Oxides <= 3.0 parts per million 3-hour rolling average by volume on a dry basis corrected to 15% O2 when EQUI 16 combusts natural gas. This



limit does not apply during startup, shutdown, malfunction, or tuning. This limit does not apply until after the shakedown period ends. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(1)(i) & Minn. R. 7007.3000]

5.21.5 The Permittee shall limit Carbon Monoxide <= 4.0 parts per million 3-hour rolling average by volume on a dry basis corrected to 15% O2. This limit applies at all times when EQUI 16 combusts natural gas and operates at full load. This limit does not apply during startup, shutdown, malfunction, or tuning. This limit does not apply until after the shakedown period ends. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.21.6 The Permittee shall limit Carbon Monoxide <= 4.7 parts per million 3-hour rolling average by volume on a dry basis corrected to 15% O2. This limit applies at all times when EQUI 16 combusts natural gas and operates at less than full load. This limit does not apply during startup, shutdown, malfunction, or tuning. This limit does not apply until after the shakedown period ends. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.21.7 The Permittee shall limit Volatile Organic Compounds <= 3.4 parts per million 3-hour block average by volume on a dry basis corrected to 15% O2 when EQUI 16 combusts natural gas. This limit does not apply during startup, shutdown, malfunction, or tuning. This limit does not apply until after the shakedown period ends. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.21.8 The Permittee shall limit Total Particulate Matter <= 0.0098 pounds per million Btu heat input 3-hour block average and not to exceed 11.9 lb/hr, also on a 3-hour block average, when combusting natural gas in EQUI 16. This limit applies at all times including during startup, shutdown, or malfunction. This limit does not apply until after the shakedown period ends. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.21.9 The Permittee shall limit PM < 10 micron <= 0.0098 pounds per million Btu heat input 3-hour block average and not to exceed 11.9 lb/hr, also on a 3-hour block average, when combusting natural gas in EQUI 16. This limit applies at all times including during startup, shutdown, or malfunction. This limit does not apply until after the shakedown period ends. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.21.10 The Permittee shall limit PM < 2.5 micron <= 0.0098 pounds per million Btu heat input 3-hour block average and not to exceed 11.9 lb/hr, also on a 3-hour block average, when combusting natural gas in EQUI 16. This limit applies at all times including during startup, shutdown, or malfunction. This limit does not apply until after the shakedown period ends. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.21.11 The Permittee shall limit Carbon Dioxide (Total) and Carbon Dioxide Equivalent <= 1000 pounds per megawatt-hour 12-month rolling average of gross energy output. This limit does



not apply until after the shakedown period ends. [40 CFR 60.5520(a), 40 CFR pt. 60, subp. TTTT(Table 2), Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.21.12 Startup and Shutdown Operating Mode is all operation of EQUI 16 at less than 60 percent of the CTG maximum potential load based on ambient conditions at the time of operation when combusting natural gas. Cold startup is when the Combustion Turbine #1 steam turbine was last online more than 48 hours prior to the startup. Warm startup is any startup that occurs when the steam turbine was last online no more than 48 hours prior to the startup. The steam turbine is online when any steam is fed to the steam turbine. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.21.13 EQUI 16 Startup, Shutdown, and Malfunction: The terms "startup", "shutdown", and "malfunction" shall have the same meanings as defined in 40 CFR Section 60.2. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.21.14 The Permittee shall restrict startup and shutdown operation for the CTG/DB (EQUI 16/EQUI 17) to the shortest time period possible to restrict emissions of PM, PM10, NOx, CO, and VOC. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.21.15 Control Equipment Operation During Startup and Shutdown: Operation of TREA 10, TREA 11, and TREA 12 is not required during EQUI 16 startup. During shutdown, control equipment operation shall continue as long as is physically possible. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.21.16 The Permittee shall limit Nitrogen Oxides <= 41.9 tons per year 12-month rolling sum during cold startups, warm startups and shutdowns on natural gas. NOx is limited to 414 lbs per cold startup event, 220 lbs per warm startup event, and 27 lbs per shutdown event on natural gas. This limit does not apply until after the shakedown period ends. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.21.17 The Permittee shall limit Carbon Monoxide <= 666.63 tons per year 12-month rolling sum during cold startups, warm startups and shutdowns on natural gas. CO is limited to 5919 lbs per cold startup event, 3788 lbs per warm startup event, and 301 lbs per shutdown event on natural gas. This limit does not apply until after the shakedown period ends. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.21.18 The Permittee shall limit Volatile Organic Compounds <= 333.32 tons per year 12-month rolling sum during cold startups, warm startups and shutdowns on natural gas. VOC is limited to 2959.5 lbs per cold startup event, 1894.0 lbs per warm startup event, and 150.5 lbs per shutdown event on natural gas. This limit does not apply until after the shakedown period ends. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.21.19 HAP Emissions Monitoring: The Permittee shall determine STRU 20 formaldehyde, n-hexane, other single HAPs, and total



HAP emissions using daily heat input records, daily operating hours, and applicable emission factors as specified in this permit. [Minn. R. 7007.0800, subp. 4, Minn. R. 7011.7000, Title I Condition: Avoid major source under 40 CFR 63.2]

5.21.20 Daily Heat Input Monitoring: Once each calendar day, the Permittee shall calculate and record total EQUI 16 heat input (in million Btus) for each of the three defined EQUI 16 operating levels (<60% load, 60% - <90% load, and 90% or greater load) during the previous operating day. If EQUI 17 is operated, the Permittee shall calculate and separately record EQUI 17 heat input (in million Btus) for the previous operating day. EQUI 16 operating load is determined on an hourly basis according to the CTG operating capacity for the ambient conditions at the time of operation. [Minn. R. 7007.0800, subp. 4, Minn. R. 7011.7000, Title I Condition: Avoid major source under 40 CFR 63.2]

5.21.21 Determination of Formaldehyde and n-Hexane Emission Factors For Emission Calculations: 1. The Permittee shall determine the load-dependent formaldehyde emission factors for calculating formaldehyde emissions from combusting natural gas (NG) using the results from the most recent MPCA-approved and reviewed stack test as follows: a. The NG formaldehyde factor for determining emissions from operation at less than 60 percent load shall be the average of three test runs, or the maximum one hour test run as allowed by this permit, at 15 to 30 percent load; b. The NG formaldehyde factor for determining emissions from operation at 60 to less than 90 percent load shall be the average of three test runs, or the maximum one hour test run as allowed by this permit, at 60 to 70 percent load; c. The NG formaldehyde factor for determining emissions from operation equal to or greater than 90 percent load (with or without EQUI 17 operating) shall be the average of three test runs, or the maximum one hour test run as allowed by this permit, at 90 to 100 percent load (baseload with EQUI 17 operating). 2. The NG n-hexane emission factor is the factor determined while combusting NG at 90 to 100 percent load (baseload with EQUI 17 operating) from the most recent MPCA-approved and reviewed stack test. The Permittee shall use this n-hexane emission factor for calculating n-hexane emissions from combusting NG at all loads. NG formaldehyde and n-hexane emission factors are revised according to the requirements under 'Protocol for Re-Setting Formaldehyde and n-Hexane Emission Factors' in this permit



under Subject Item STRU 20. [Minn. R. 7007.0800, subp. 4]

5.21.22 Monthly HAPs Emissions Monitoring and Recordkeeping: By the last day of each month, the Permittee shall calculate and record monthly STRU 20 formaldehyde, n-hexane, and total HAP emissions for the previous calendar month. NG HAP Emissions: Formaldehyde and n-hexane emissions from NG combustion are determined using daily EQUI 16 and EQUI 17 heat input data and the applicable lb/mmBtu emission factor. For all other single HAPs from NG combustion, EQUI 16 and EQUI 17 single HAP emissions are determined for each emission unit using each unit's daily heat input records and applicable AP-42 emission factor. Total HAP emissions are determined by summing all individual HAPs data for the previous calendar month. Applicable emission factors are as follows: 1. The NG lb/mmBtu formaldehyde and n-hexane emission factors are the average of the three test runs, respectively, from the most recent MPCA-approved and reviewed stack test. 2. Notwithstanding item 1 above, upon issuance of this permit the Permittee has the option to use the maximum one-hour formaldehyde emission rate of the three one-hour test runs while combusting NG (instead of the average of the three test runs) determined during the most recent MPCA-approved and reviewed stack test for each of the three tested operating loads for calculating formaldehyde emissions, if the Permittee prefers to test for the multi-load NG formaldehyde emission factors at 60-month intervals. This requirement may be implemented by the Permittee if the multi-load NG formaldehyde test frequency would otherwise be at an interval more frequent than 60 months based on the most current MPCA-approved and reviewed multi-load NG formaldehyde stack test results and MPCA emission factor stack test frequency guidance. See COMG 5 for Formaldehyde, n-Hexane and HAPs Total limits. [Minn. R. 7007.0800, subp. 4]

5.21.23 Protocol for Re-Setting Emission Factors Used For Calculating Formaldehyde and n-Hexane Emissions From NG Combustion: The Permittee shall conduct performance testing under conditions that produce: 1. The maximum formaldehyde emission rate for each of the three operating ranges (<60%, 60% - <90%, and 90% or greater load (also referred to as 'full load')); and,



2. The maximum n-hexane emission rate at 90% or greater load. The Permittee shall use U.S. EPA Reference Methods 323 and 18 to measure formaldehyde and n-hexane emissions, respectively, as required elsewhere in this permit. The Permittee shall report each test result as a lb/mmBtu emission factor in the performance test report required by Minn. R. 7017.2035, subp. 1. The emission factors for calculating formaldehyde emissions at each of the three operating ranges, and n-hexane emissions at full load, shall be re-set to the 3-hour average emission rate in lb/mmBtu, measured during the most recent MPCA-approved applicable emission factor performance. Notwithstanding the previous paragraph and as allowed elsewhere in Subject Item STRU 20 of this permit, if the Permittee elects to reduce formaldehyde testing frequency while combusting NG from once every 30 months to once every 60 months for all three operating load ranges by using the highest one-hour test run for each operating load range, the formaldehyde emission factor shall be reset to the maximum one-hour test value from the three one-hour test runs for each of the three operating load range (<60%, 60% - <90%, and 90% or greater load) tests. The new emission factors (for calculating formaldehyde and n-hexane emissions) determined using this Protocol shall be effective upon receipt of the Notice of Compliance (NOC) letter that approves the test results and shall be incorporated into the permit during the next permit amendment. [Minn. R. 7011.7000, Title I Condition: Avoid major source under 40 CFR 63.2]

5.21.24 Notwithstanding the Protocol detailed above, the MPCA reserves the right to set operational limits and requirements as allowed under Minn. R. 7017.2025. If the MPCA sets limits, the new limits shall be implemented upon receipt of the NOC letter that notifies the Permittee of preliminary approval. The limits set according to Minn. R. 7017.2025 are final upon issuance of a permit amendment incorporating the change. [Minn. R. 7017.2025]

5.21.25 The Permittee must apply for and obtain a major permit amendment if the Permittee wishes to deviate from the Protocol for Re-Setting Emission Factors Used For Calculating Formaldehyde and n-Hexane Emissions From Natural Gas Combustion established by this permit. [Minn. R. 7007.1500, subp. 1]

5.21.26 See EQUI 21 for additional NOx CEMS requirements and EQUI 22 for additional CO CEMS requirements. [Minn. R. 7007.0800, subp. 2]



5.21.27 Emissions Monitoring: The Permittee shall measure or calculate SO2, NOx, and CO2 emission rates in accordance with 40 CFR pt. 75. [40 CFR 75.10, Minn. R. 7017.1020]

5.21.28 Emissions Monitoring: The Permittee shall use a Continuous Emissions Monitoring System (CEMS) to measure NOx emissions, and measure or calculate SO2 and CO2 in accordance with 40 CFR pt. 75 for STRU 20. The Permittee shall measure NOx emissions in ppmvd corrected to 15% oxygen and automatically calculate and record the 3-hour average NOx emission rate. NOx ppmvd emission data shall also be converted to lb/mmBtu as required by 40 CFR pt. 75. [40 CFR 75.10, Minn. R. 7017.1006, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.21.29 Emissions Monitoring: The Permittee shall use a CEMS to measure CO emissions in ppmvd corrected to 15% oxygen. The Permittee shall automatically calculate and record the 3-hour average CO emission rate. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.21.30 Operating Load and Operating Conditions Monitoring - The Permittee shall: 1. Continuously monitor, determine, and record the hourly heat input rate (mmBtu/hr) for EQUI 16/EQUI 17 using the methods specified at 40 CFR pt. 75, Appendix D Section 3.4; 2. Monitor and record the time and duration of each startup, shutdown, and malfunction; 3. Record the start and stop time of each steam turbine-generator on-line and off-line period. 4. Monitor and record the percent operating load (using the combustion turbine automated control system and the CEMS data acquisition and handling system). [40 CFR 75.10, Minn. R. 7007.0800, subp. 4, Minn. R. 7011.7000, Minn. R. 7017.1006, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000, Title I Condition: Avoid major source under 40 CFR 63.2]

5.21.31 NOx CEMS Quality Assurance/Quality Control (QA/QC): The Permittee shall operate, calibrate, and maintain the NOx CEMS according to the QA/QC procedure in 40 CFR pt. 75, Appendix B, as amended. [40 CFR 75.21]

5.21.32 NOx CEMS and CO CEMS Continuous Operation: The NOx CEMS and CO CEMS must be operated and data recorded during all periods of emission unit operation including periods of emission unit start-up, shutdown, or malfunction except for periods of acceptable monitor downtime. This requirement applies whether or not a numerical emission limit applies during these periods. The CEMS must not be bypassed except in emergencies where failure to bypass would endanger human health, safety, or plant equipment. Acceptable CEM downtime includes reasonable periods as listed in items A, B, C and D of Minn. R. 7017.1090, subp. 2. [Minn. R. 7017.1090, subp. 1]

5.21.33 NOx and CO CAM Requirements: The Permittee shall use the



NOx CEMS and CO CEMS to satisfy the requirements of 40 CFR pt. 64. [40 CFR 64.3(d), Minn. R. 7017.0200]

5.21.34 VOC CAM Requirements: The Permittee shall use the CO CEMS for VOC compliance assurance monitoring. Compliance with the CO limit indicated by the CO CEMS assures that VOC emissions are in compliance with the VOC limit. The Permittee shall demonstrate this correlation by recording and comparing CO CEMS emissions data during STRU 20 VOC performance testing, with results of the VOC testing. The correlation shall be valid only if testing demonstrates that VOC emissions comply with the applicable VOC limit at the same time that CO emissions (measured by the CO CEMS) comply with the applicable CO limit, and the CO CEMS certification testing has been satisfactorily completed. [40 CFR 64.3(a), 40 CFR 64.6(b), Minn. R. 7017.0200]

5.21.35 Documentation of Need for Improved VOC Monitoring: If the Permittee fails to achieve compliance with the VOC emission limit when the CO CEMS did not provide an indication of a VOC emissions excursion or exceedance while the CO CEMS provided valid CO emissions data, or the results of VOC performance testing document a need to modify the existing CO indicator of VOC emissions compliance, the Permittee shall promptly notify the MPCA and, if necessary, submit a permit amendment application to address the necessary monitoring changes. [40 CFR 64.7(e), Minn. R. 7017.0200]

5.21.36 Recordkeeping: The Permittee must retain records of all CEMS monitoring data and support information for a period of five years from the date of the monitoring sample, measurement or report. Records shall be kept at the source. [40 CFR 75.57, Minn. R. 7017.1130]

5.21.37 The Permittee shall limit Nitrogen Oxides <= 15 parts per million 30-day rolling average by volume at 15 percent O2 or 54 ng/J of useful output (0.43 lb/MWh) while combusting natural gas when the turbine is operating at or above 75 percent of peak load and when operating at ambient temperatures of 0 degrees F or above. This limit applies to EQUI 16 and EQUI 17. [40 CFR 60.4320(a), 40 CFR pt. 60, subp. KKKK(Table 1)]

5.21.38 The Permittee shall limit Nitrogen Oxides <= 96 parts per million 30-day rolling average by volume at 15 percent O2 or 590 ng/J of useful output (4.70 lb/MWh) while combusting natural gas and the turbine is operating at less than 75 percent of peak load or operating at ambient temperatures less than 0 degrees F. This limit applies to EQUI 16 and EQUI 17. [40 CFR 60.4320(a), 40 CFR pt. 60, subp. KKKK(Table 1)]

5.21.39 The Permittee shall limit Sulfur Dioxide <= 0.060 pounds per million Btu heat input (26 ng SO2/J). [40 CFR 60.4330(a)(2)]

5.21.40 The Permittee must operate and maintain EQUI 16, EQUI 17, air pollution control equipment, and monitoring equipment in a manner consistent with good air pollution control practices for minimizing emissions at all times including during startup,



shutdown, and malfunction. [40 CFR 60.4333(a)]

5.21.41 The Permittee shall either: (1) Determine compliance with the applicable NOx emissions limits by measuring the emissions combined with the emissions from the other unit(s) utilizing the common heat recovery unit; or (2) Develop, demonstrate, and provide information satisfactory to the Administrator on methods for apportioning the combined gross energy output from the heat recovery unit for each of the affected combustion turbines. The Administrator may approve such demonstrated substitute methods for apportioning the combined gross energy output measured at the steam turbine whenever the demonstration ensures accurate estimation of emissions related under this part. [40 CFR 60.4333(b)]

5.21.42 Each NOx diluent CEMS must be installed and certified according to Performance Specification 2 (PS 2) in 40 CFR pt. 60, appendix B, except the 7-day calibration drift is based on unit operating days, not calendar days. With state approval, Procedure 1 in 40 CFR pt. 60, appendix F is not required. Alternatively, a NOx diluent CEMS that is installed and certified according to 40 CFR pt. 75, appendix A is acceptable for use under 40 CFR pt. 60, subp. KKKK. The relative accuracy test audit (RATA) of the CEMS shall be performed on a lb/MMBtu basis. [40 CFR 60.4345(a)]

5.21.43 As specified in 40 CFR Section 60.13(e)(2), during each full unit operating hour, both the NOx monitor and the diluent monitor must complete a minimum of one cycle of operation (sampling, analyzing, and data recording) for each 15-minute quadrant of the hour, to validate the hour. For partial unit operating hours, at least one valid data point must be obtained with each monitor for each quadrant of the hour in which the unit operates. For unit operating hours in which required quality assurance and maintenance activities are performed on the CEMS, a minimum of two valid data points (one in each of two quadrants) are required for each monitor to validate the NOx emission rate for the hour. [40 CFR 60.4345(b)]

5.21.44 Each fuel flowmeter shall be installed, calibrated, maintained, and operated according to the manufacturer's instructions. Alternatively, with state approval, fuel flowmeters that meet the installation, certification, and quality assurance requirements of 40 CFR pt. 75, appendix D are acceptable for use under 40 CFR pt. 60, subp. KKKK. [40 CFR 60.4345(c)]

5.21.45 Each watt meter, steam flow meter, and each pressure or temperature measurement device shall be installed, calibrated, maintained, and operated according to manufacturer's instructions. [40 CFR 60.4345(d)]

5.21.46 The Permittee shall develop and keep on-site a quality assurance (QA) plan for all of the continuous monitoring equipment described in 40 CFR Section 60.4345(a), (c), and (d). For the CEMS and fuel flow meters, the Permittee may, with



state approval, satisfy the requirements of 40 CFR Section 60.4345(e) by implementing the QA program and plan described in 40 CFR pt. 75, appendix B, section 1. [40 CFR 60.4345(e)]

5.21.47 All CEMS data must be reduced to hourly averages as specified in 40 CFR Section 60.13(h). [40 CFR 60.4350(a)]

5.21.48 For each unit operating hour in which a valid hourly average, as described in 40 CFR Section 60.4345(b), is obtained for both NOx and diluent monitors, the data acquisition and handling system must calculate and record the hourly NOx emission rate in units of ppm or lb/MMBtu, using the appropriate equation from method 19 in 40 CFR pt. 60, appendix A. For any hour in which the hourly average O2 concentration exceeds 19.0 percent O2 (or the hourly average CO2 concentration is less than 1.0 percent CO2), a diluent cap value of 19.0 percent O2 or 1.0 percent CO2 (as applicable) may be used in the emission calculations. [40 CFR 60.4350(b)]

5.21.49 Correction of measured NOx concentrations to 15 percent O2 is not allowed. [40 CFR 60.4350(c)]

5.21.50 If the Permittee has installed and certified a NOx diluent CEMS to meet the requirements of 40 CFR pt. 75, states can approve that only quality assured data from the CEMS shall be used to identify excess emissions under 40 CFR pt. 60, subp. KKKK. Periods where the missing data substitution procedures in 40 CFR pt. 75, subpart D are applied are to be reported as monitor downtime in the excess emissions and monitoring performance report required under 40 CFR Section 60.7(c). [40 CFR 60.4350(d)]

5.21.51 All required fuel flow rate, steam flow rate, temperature, pressure, and megawatt data must be reduced to hourly averages. [40 CFR 60.4350(e)]

5.21.52 Calculate the hourly average NOx emission rates, in units of the emission standards under 40 CFR Section 60.4320, using ppm for units complying with the concentration limit. [40 CFR 60.4350(f)]

5.21.53 The Permittee must monitor the total sulfur content of the fuel being fired in the turbine, except as provided in 40 CFR Section 60.4365. The sulfur content of the fuel must be determined using total sulfur methods described in 40 CFR Section 60.4415 or 40 CFR pt. 75. Alternatively, if the total sulfur content of the gaseous fuel during the most recent performance test was less than half the applicable limit, ASTM D4084, D4810, D5504, or D6228, or Gas Processors Association Standard 2377 (all of which are incorporated by reference, see 40 CFR Section 60.17), which measure the major sulfur compounds, may be used. [40 CFR 60.4360]

5.21.54 The Permittee may elect not to monitor the total sulfur content of the fuel combusted in the turbine, if the fuel is demonstrated not to exceed potential sulfur emissions of 26 ng SO2/J (0.060 lb SO2/MMBtu) heat input for units located in continental areas. The Permittee must use one of the following sources of information to make the required demonstration:



(a) The fuel quality characteristics in a current, valid purchase contract, tariff sheet or transportation contract for the fuel, specifying that the total sulfur content for natural gas use in continental areas is 20 grains of sulfur or less per 100 standard cubic feet, has potential sulfur emissions of less than less than 26 ng SO2/J (0.060 lb SO2/MMBtu) heat input for continental areas; or (b) Representative fuel sampling data which show that the sulfur content of the fuel does not exceed 26 ng SO2/J (0.060 lb SO2/MMBtu) heat input for continental areas. At a minimum, the amount of fuel sampling data specified in section 2.3.1.4 or 2.3.2.4 of 40 CFR pt. 75, appendix D is required. [40 CFR 60.4365]

5.21.55 The frequency of determining the sulfur content of the fuel must be as follows: (b) Gaseous fuel. If the Permittee elects not to demonstrate sulfur content using options in 40 CFR Section 60.4365, and the fuel is supplied without intermediate bulk storage, the sulfur content value of the gaseous fuel must be determined and recorded once per unit operating day. (c) Custom schedules. Notwithstanding the requirements of 40 CFR Section 60.4370(b), operators or fuel vendors may develop custom schedules for determination of the total sulfur content of gaseous fuels, based on the design and operation of the affected facility and the characteristics of the fuel supply. Except as provided in 40 CFR Section 60.4370(c)(1) and (c)(2), custom schedules shall be substantiated with data and shall be approved by the Administrator before they can be used to comply with the standard in 40 CFR Section 60.4330. (1) The two custom sulfur monitoring schedules set forth in 40 CFR Section 60.4370(c)(1)(i) through (iv) and in 40 CFR Section 60.4370(c)(2) are acceptable, without prior Administrative approval: (i) The Permittee shall obtain daily total sulfur content measurements for 30 consecutive unit operating days, using the applicable methods specified in 40 CFR pt. 60, subp. KKKK. Based on the results of the 30 daily samples, the required frequency for subsequent monitoring of the fuel's total sulfur content shall be as specified in 40 CFR Section 60.4370(c)(1)(ii), (iii), or (iv), as applicable. (ii) If none of the 30 daily measurements of the fuel's total sulfur content exceeds half the applicable standard, subsequent sulfur content monitoring may be performed at 12-month intervals. If any of the samples taken at 12-month intervals has a total sulfur content greater than half but less than the applicable limit, follow the procedures in 40 CFR Section 60.4370(c)(1)(iii). If any measurement exceeds the



applicable limit, follow the procedures in 40 CFR Section 60.4370(c)(1)(iv). (iii) If at least one of the 30 daily measurements of the fuel's total sulfur content is greater than half but less than the applicable limit, but none exceeds the applicable limit, then: (A) Collect and analyze a sample every 30 days for 3 months. If any sulfur content measurement exceeds the applicable limit, follow the procedures in 40 CFR Section 60.4370(c)(1)(iv). Otherwise, follow the procedures in 40 CFR Section 60.4370(c)(1)(iii)(B). (B) Begin monitoring at 6-month intervals for 12 months. If any sulfur content measurement exceeds the applicable limit, follow the procedures in 40 CFR Section 60.4370(c)(1)(iv). Otherwise, follow the procedures in 40 CFR Section 60.4370(c)(1)(iii)(C). (C) Begin monitoring at 12-month intervals. If any sulfur content measurement exceeds the applicable limit, follow the procedures in 40 CFR Section 60.4370(c)(1)(iv). Otherwise, continue to monitor at this frequency. (iv) If a sulfur content measurement exceeds the applicable limit, immediately begin daily monitoring according to 40 CFR Section 60.4370(c)(1)(i). Daily monitoring shall continue until 30 consecutive daily samples, each having a sulfur content no greater than the applicable limit, are obtained. At that point, the applicable procedures of 40 CFR Section 60.4370(c)(1)(ii) or (iii) shall be followed. (continued below). [40 CFR 60.4370(b) - (c)(1)]

5.21.56 (continued from above) (2) The Permittee may use the data collected from the 720-hour sulfur sampling demonstration described in section 2.3.6 of 40 CFR pt. 75, appendix D to determine a custom sulfur sampling schedule, as follows: (i) If the maximum fuel sulfur content obtained from the 720 hourly samples does not exceed 20 grains/100 scf, no additional monitoring of the sulfur content of the gas is required, for the purposes of 40 CFR pt. 60, subp. KKKK. (ii) If the maximum fuel sulfur content obtained from any of the 720 hourly samples exceeds 20 grains/100 scf, but none of the sulfur content values (when converted to weight percent sulfur) exceeds half the applicable limit, then the minimum required sampling frequency shall be one sample at 12 month intervals. (iii) If any sample result exceeds half the applicable limit, but none exceeds the applicable limit, follow the provisions of 40 CFR Section 60.4370(c)(1)(iii). (iv) If the sulfur content of any of the 720 hourly samples exceeds the applicable limit, follow the provisions of 40 CFR Section 60.4370(c)(1)(iv). [40 CFR 60.4370(c)(2)]

5.21.57 The Permittee must submit reports of excess emissions and



monitor downtime, in accordance with 40 CFR Section 60.7(c). Excess emissions must be reported for all periods of unit operation, including start-up, shutdown, and malfunction. [40 CFR 60.4375(a)]

5.21.58 For turbines using continuous emission monitoring, as described in 40 CFR Sections 60.4335(b) and 60.4345: An excess emissions is any unit operating period in which the 4-hour or 30-day rolling average NOx emission rate exceeds the applicable emission limit in 40 CFR Section 60.4320. For the purposes of 40 CFR pt. 60, subp. KKKK, a 4-hour rolling average NOx emission rate is the arithmetic average of the average NOx emission rate in ppm or ng/J (lb/MWh) measured by the continuous emission monitoring equipment for a given hour and the three unit operating hour average NOx emission rates immediately preceding that unit operating hour. Calculate the rolling average if a valid NOx emission rate is obtained for at least 3 of the 4 hours. For the purposes of 40 CFR pt. 60, subp. KKKK, a 30-day rolling average NOx emission rate is the arithmetic average of all hourly NOx emission data in ppm or ng/J (lb/MWh) measured by the continuous emission monitoring equipment for a given day and the twenty-nine unit operating days immediately preceding that unit operating day. A new 30-day average is calculated each unit operating day as the average of all hourly NOx emissions rates for the preceding 30 unit operating days if a valid NOx emission rate is obtained for at least 75 percent of all operating hours. [40 CFR 60.4380(b)(1)]

5.21.59 A period of monitor downtime is any unit operating hour in which the data for any of the following parameters are either missing or invalid: NOx concentration, CO2 or O2 concentration, fuel flow rate, steam flow rate, steam temperature, steam pressure, or megawatts. The steam flow rate, steam temperature, and steam pressure are only required if the Permittee will use this information for compliance purposes. [40 CFR 60.4380(b)(2)]

5.21.60 For operating periods during which multiple emissions standards apply, the applicable standard is the average of the applicable standards during each hour. For hours with multiple emissions standards, the applicable limit for that hour is determined based on the condition that corresponded to the highest emissions standard. [40 CFR 60.4380(b)(3)]

5.21.61 For turbines required to monitor combustion parameters or parameters that document proper operation of the NOx emission controls: An excess emission is a 4-hour rolling unit operating hour average in which any monitored parameter does not achieve the target value or is outside the acceptable range defined in the parameter monitoring plan for the unit. [40 CFR 60.4380(c)(1)]

5.21.62 A period of monitor downtime is a unit operating hour in which any of the required parametric data are either not recorded or are invalid. [40 CFR 60.4380(c)(2)]



5.21.63 For samples of gaseous fuel obtained using daily sampling or flow proportional sampling, an excess emission occurs each unit operating hour included in the period beginning on the date and hour of any sample for which the sulfur content of the fuel being fired in the combustion turbine exceeds the applicable limit and ending on the date and hour that a subsequent sample is taken that demonstrates compliance with the sulfur limit. [40 CFR 60.4385(a)]

5.21.64 A period of monitor downtime begins when a required sample is not taken by its due date. A period of monitor downtime also begins on the date and hour of a required sample, if invalid results are obtained. The period of monitor downtime ends on the date and hour of the next valid sample. [40 CFR 60.4385(c)]

5.21.65 Perform a minimum of nine RATA reference method runs, with a minimum time per run of 21 minutes, at a single load level, within plus or minus 25 percent of 100 percent of peak load. The ambient temperature must be greater than 0 degrees F during the RATA runs. [40 CFR 60.4405(a)]

5.21.66 For each RATA run, concurrently measure the heat input to the unit using a fuel flow meter (or flow meters) and measure the electrical and thermal output from the unit. [40 CFR 60.4405(b)]

5.21.67 Use the test data both to demonstrate compliance with the applicable NOx emission limit under 40 CFR Section 60.4320 and to provide the required reference method data for the RATA of the CEMS described under 40 CFR Section 60.4335. [40 CFR 60.4405(c)]

5.21.68 Compliance with the applicable emission limit in 40 CFR Section 60.4320 is achieved if the arithmetic average of all of the NOx emission rates for the RATA runs, expressed in units of ppm or lb/MWh, does not exceed the emission limit. [40 CFR 60.4405(d)]

5.21.69 When monitoring combustion parameters in accordance with 40 CFR Section 60.4340, the appropriate parameters must be continuously monitored and recorded during each run of the initial performance test, to establish acceptable operating ranges, for purposes of the parameter monitoring plan for the affected unit, as specified in 40 CFR Section 60.4355. [40 CFR 60.4410]

5.21.70 The Permittee must conduct an initial performance test, as required in 40 CFR Section 60.8. Subsequent SO2 performance tests shall be conducted on an annual basis (no more than 14 calendar months following the previous performance test). There are three methodologies that the Permittee may use to conduct the performance tests. (1) If the Permittee chooses to periodically determine the sulfur content of the fuel combusted in the turbine, a representative fuel sample would be collected following ASTM D5287 (incorporated by reference, see 40 CFR Section 60.17) for natural gas. The fuel analyses of this section may be



performed either by the Permittee, a service contractor retained by the Permittee, the fuel vendor, or any other qualified agency. Analyze the samples for the total sulfur content of the fuel using: For gaseous fuels, ASTM D1072, or alternatively D3246, D4084, D4468, D4810, D6228, D6667, or Gas Processors Association Standard 2377 (all of which are incorporated by reference, see 40 CFR Section 60.17). (2) Measure the SO2 concentration (in parts per million (ppm)), using EPA Methods 6, 6C, 8, or 20 in 40 CFR pt. 60, appendix A. In addition, the American Society of Mechanical Engineers (ASME) standard, ASME PTC 19-10-1981-Part 10, "Flue and Exhaust Gas Analyses," manual methods for sulfur dioxide (incorporated by reference, see 40 CFR Section 60.17) can be used instead of EPA Methods 6 or 20. (3) Measure the SO2 and diluent gas concentrations, using either EPA Methods 6, 6C, or 8 and 3A, or 20 in 40 CFR pt. 60, appendix A. In addition, the Permittee may use the manual methods for sulfur dioxide ASME PTC 19-10-1981-Part 10 (incorporated by reference, see 40 CFR Section 60.17). Concurrently measure the heat input to the unit, using a fuel flowmeter (or flowmeters), and measure the electrical and thermal output of the unit. Use EPA Method 19 in 40 CFR pt. 60, appendix A to calculate the SO2 emission rate in lb/MMBtu. Then, use Equations 1 and, if necessary, 2 and 3 in 40 CFR Section 60.4350(f) to calculate the SO2 emission rate in lb/MWh. [40 CFR 60.4415(a)(1) - (3)]

5.21.71 Use methods in 40 CFR pt. 98, subp. C including flow monitoring of fuel usage and fuel gas analysis. Calculate emissions following procedures specified in 40 CFR pt. 98, subp. C with a conversion from metric tons to short tons. The Permittee shall calculate and record the 12-month rolling average of gross energy output (net) of CO2e emissions by the 15th day of each month for the 12-month rolling average periods ending on the last day of the preceding month. [40 CFR 60.5520(a), 40 CFR pt. 60, subp. TTTT(Table 2), 40 CFR pt. 98, subp. C, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.21.72 Except as specified in 40 CFR Section 60.5520(c) and (d), the Permittee must comply with the applicable gross energy output standard, and the operating permit must include monitoring, recordkeeping, and reporting methodologies based on the applicable gross energy output standard. For the remainder of this subpart (for sources that do not qualify under 40 CFR Section 60.5520(c) and (d)), where the term "gross or net energy output" is used, the term that applies is "gross energy output.". [40 CFR 60.5520(b)]

5.21.73 For each affected EGU subject to a CO2 emissions standard based on a 12-operating-month rolling average, the Permittee



must determine compliance monthly by calculating the average CO2 emissions rate for the affected EGU at the end of the initial and each subsequent 12-operating-month period. [40 CFR 60.5525(a)(1)]

5.21.74 At all times the Permittee must operate and maintain each affected EGU, including associated equipment and monitors, in a manner consistent with safety and good air pollution control practice. The Administrator will determine if the Permittee is using consistent operation and maintenance procedures based on information available to the Administrator that may include, but is not limited to, fuel use records, monitoring results, review of operation and maintenance procedures and records, review of reports required by 40 CFR pt. 60, subp. TTTT, and inspection of the EGU. [40 CFR 60.5525(b)]

5.21.75 Within 30 days after the end of the initial compliance period (i.e., no more than 30 days after the first 12-operating-month compliance period), the Permittee must make an initial compliance determination for the affected EGU(s) with respect to the applicable emissions standard in 40 CFR pt. 60, subp. TTTT table 1 or 2, in accordance with the requirements in this subpart. The first operating month included in the initial 12-operating-month compliance period shall be determined as follows: (1) For an affected EGU that commences commercial operation (as defined in 40 CFR Section 72.2) on or after October 23, 2015, the first month of the initial compliance period shall be the first operating month (as defined in 40 CFR Section 60.5580) after the calendar month in which emissions reporting is required to begin under 40 CFR Section 63.5555(c)(3)(i), for units subject to the Acid Rain Program. [40 CFR 60.5525(c)(1)(i)]

5.21.76 The Permittee must prepare a monitoring plan to quantify the hourly CO2 mass emission rate (tons/h), in accordance with the applicable provisions in 40 CFR Section 75.53(g) and (h). The electronic portion of the monitoring plan must be submitted using the ECMPS Client Tool and must be in place prior to reporting emissions data and/or the results of monitoring system certification tests under 40 CFR pt. 60, subp. TTTT. The monitoring plan must be updated as necessary. Monitoring plan submittals must be made by the Designated Representative (DR), the Alternate DR, or a delegated agent of the DR (see 40 CFR Section 60.5555(c)). [40 CFR 60.5535(a)]

5.21.77 The Permittee may determine the hourly CO2 mass emissions according to 40 CFR Section 60.5535(c)(1) through (4). (1) The Permittee must implement the applicable procedures in 40 CFR pt. 75, appendix D to determine hourly EGU heat input rates (MMBtu/h), based on hourly measurements of fuel flow rate and periodic determinations of the gross calorific value (GCV) of each fuel combusted.



(2) For each measured hourly heat input rate, use Equation G-4 in 40 CFR pt. 75, appendix G to calculate the hourly CO2 mass emission rate (tons/h). The Permittee may determine site-specific carbon-based F-factors (Fc) using Equation F-7b in 40 CFR pt. 75, appendix F section 3.3.6, and the Permittee may use these Fc values in the emissions calculations instead of using the default Fc values in the Equation G-4 nomenclature. (3) For each "valid operating hour" (as defined in 40 CFR Section 60.5540(a)(1), multiply the hourly tons/h CO2 mass emission rate from 40 CFR Section 60.5535(c)(2) by the EGU or stack operating time in hours (as defined in 40 CFR Section 72.2), to convert it to tons of CO2. Then, multiply the result by 909.1 to convert from tons of CO2 to kg. Round off to the nearest two significant figures. (4) The hourly CO2 tons/h values and EGU (or stack) operating times used to calculate CO2 mass emissions are required to be recorded under 40 CFR Section 75.57(e) and must be reported electronically under 40 CFR Section 75.64(a)(6). The Permittee must use these data to calculate the hourly CO2 mass emissions. [40 CFR 60.5535(c)(1) - (4)]

5.21.78 The Permittee must install, calibrate, maintain, and operate a sufficient number of watt meters to continuously measure and record the hourly gross electric output, as applicable, from the affected EGU(s). These measurements must be performed using 0.2 class electricity metering instrumentation and calibration procedures as specified under ANSI Standards No. C12.20 (incorporated by reference, see 40 CFR Section 60.17). The plan shall ensure that you install, calibrate, maintain, and operate meters to record each component of the determination, hour-by-hour. [40 CFR 60.5535(d)(1)]

5.21.79 For the initial and each subsequent 12-operating-month rolling average compliance period, the Permittee must follow the procedures in 40 CFR Section 60.5540(a)(1) through (7) to calculate the CO2 mass emissions rate for the affected EGU(s) in units of the applicable emissions standard (i.e., either kg/MWh or lb/MMBtu). The Permittee must use the hourly CO2 mass emissions calculated under 40 CFR Section 60.5535(b) or (c), as applicable, and either the generating load data from 40 CFR Section 60.5535(d)(1) for output-based calculations. (1) Each compliance period shall include only "valid operating hours" in the compliance period, i.e., operating hours for which: (i) "Valid data" (as defined in 40 CFR Section 60.5580) are obtained for all of the parameters used to determine the hourly CO2 mass emissions (kg); and (ii) The corresponding hourly gross or net energy output value



is also valid data (Note: For hours with no useful output, zero is considered to be a valid value). (2) The Permittee must exclude operating hours in which: (i) The substitute data provisions of 40 CFR part 75 are applied for any of the parameters used to determine the hourly CO2 mass emissions; or (ii) An exceedance of the full-scale range of a continuous emission monitoring system occurs for any of the parameters used to determine the hourly CO2 mass emissions; or (iii) The total gross or net energy output (Pgross/net) is unavailable. (3) For each compliance period, at least 95 percent of the operating hours in the compliance period must be valid operating hours, as defined in 40 CFR Section 60.5540(a)(1). (4) The Permittee must calculate the total CO2 mass emissions by summing the valid hourly CO2 mass emissions values from 40 CFR Section 60.5535 for all of the valid operating hours in the compliance period. (5) Sources subject to output based standards. For each valid operating hour of the compliance period that was used in 40 CFR Section 60.5540(a)(4) to calculate the total CO2 mass emissions, the Permittee must determine Pgross/net (the corresponding hourly gross or net energy output in MWh) according to the procedures in 40 CFR Section 60.5540(a)(3)(i) and (ii), as appropriate for the type of affected EGU(s). For an operating hour in which a valid CO2 mass emissions value is determined according to 40 CFR Section 60.5540(a)(1)(i), if there is no gross or net electrical output, but there is mechanical or useful thermal output, the Permittee must still determine the gross or net energy output for that hour. In addition, for an operating hour in which a valid CO2 mass emissions value is determined according to 40 CFR Section 60.5540(a)(1)(i), but there is no (i.e., zero) gross electrical, mechanical, or useful thermal output, the Permittee must use that hour in the compliance determination. For hours or partial hours where the gross electric output is equal to or less than the auxiliary loads, net electric output shall be counted as zero for this calculation. (i) Calculate Pgross/net for the affected EGU using the following equation. All terms in the equation must be expressed in units of megawatt-hours (MWh). To convert each hourly gross or net energy output (consistent with 40 CFR Section 60.5520) value reported under 40 CFR pt. 75 to MWh, multiply by the corresponding EGU or stack operating time. (continued below). [40 CFR 60.5540(a)(1) - (5)]

5.21.80 (continued from above)



Pgross/net = [(Pe)ST + (Pe)CT + (Pe)IE - (Pe)FW - (Pe)A]/TDF + [(Pt)PS + (Pt)HR + (Pt)IE] Where: Pgross/net = In accordance with 40 CFR Section 60.5520, gross or net energy output of the affected EGU for each valid operating hour (as defined in 40 CFR Section 60.5540(a)(1)) in MWh. (Pe)ST = Electric energy output plus mechanical energy output (if any) of steam turbines in MWh. (Pe)CT = Electric energy output plus mechanical energy output (if any) of stationary combustion turbine(s) in MWh. (Pe)IE = Electric energy output plus mechanical energy output (if any) of the affected EGU's integrated equipment that provides electricity or mechanical energy to the affected EGU or auxiliary equipment in MWh. (Pe)FW = Electric energy used to power boiler feedwater pumps at steam generating units in MWh. Not applicable to stationary combustion turbines, IGCC EGUs, or EGUs complying with a net energy output based standard. (Pe)A = Electric energy used for any auxiliary loads in MWh. Not applicable for determining Pgross. (Pt)PS = Useful thermal output of steam (measured relative to SATP conditions, as applicable) that is used for applications that do not generate additional electricity, produce mechanical energy output, or enhance the performance of the affected EGU. This is calculated using the equation specified in 40 CFR Section 60.5540(a)(5)(ii) in MWh. (Pt)HR = Non steam useful thermal output (measured relative to SATP conditions, as applicable) from heat recovery that is used for applications other than steam generation or performance enhancement of the affected EGU in MWh. (Pt)IE = Useful thermal output (relative to SATP conditions, as applicable) from any integrated equipment is used for applications that do not generate additional steam, electricity, produce mechanical energy output, or enhance the performance of the affected EGU in MWh. TDF = Electric Transmission and Distribution Factor of 1.0 on a 12-operating-month rolling average basis. (ii) If applicable to the affected EGU (for example, for combined heat and power), the Permittee must calculate



(Pt)PS using the following equation: (Pt)PS = Qm x H / CF Where: Qm = Measured steam flow in kilograms (kg) (or pounds (lb)) for the operating hour. H = Enthalpy of the steam at measured temperature and pressure (relative to SATP conditions or the energy in the condensate return line, as applicable) in Joules per kilogram (J/kg) (or Btu/lb). CF = Conversion factor of 3.6 × 109 J/MWh or 3.413 × 106 Btu/MWh. (6) Calculation of annual basis for standard. Sources complying with energy output-based standards must calculate the basis (i.e., denominator) of their actual annual emission rate in accordance with 40 CFR Section 60.5540(a)(6)(i). (i) In accordance with 40 CFR Section 60.5520 the Permittee must calculate the total gross or net energy output for the affected EGU's compliance period by summing the hourly gross or net energy output values for the affected EGU that you determined under 40 CFR Section 60.5540(a)(5) for all of the valid operating hours in the applicable compliance period. (7) The Permittee must calculate the CO2 mass emissions rate for the affected EGU(s) (kg/MWh) by dividing the total CO2 mass emissions value calculated according to the procedures in 40 CFR Section 60.5540(a)(4) by the total gross or net energy output value calculated according to the procedures in 40 CFR Section 60.5540(a)(6)(i). Round off the result to two significant figures if the calculated value is less than 1,000; round the result to three significant figures if the calculated value is greater than 1,000. [40 CFR 60.5540(a)(5) - (7)]

5.21.81 In accordance with 40 CFR Section 60.5520, to demonstrate compliance with the applicable CO2 emission standard, for the initial and each subsequent 12-operating-month compliance period, the CO2 mass emissions rate for the affected EGU must be determined according to the procedures specified in 40 CFR Section 60.5540(a)(1) through (7) and must be less than or equal to the applicable CO2 emissions standard in 40 CFR pt. 60, subp. TTTT table 1 or 2, or the emissions standard calculated in accordance with 40 CFR Section 60.5525(a)(2). [40 CFR 60.5540(b)]

5.21.82 The Permittee must prepare and submit the notifications specified in 40 CFR Section 60.7(a)(1) and (a)(3) and 40 CFR Section 60.19, as applicable to the affected EGU(s) (see 40 CFR pt. 60, subp. TTTT table 3). [40 CFR 60.5550(a)]



5.21.83 The Permittee must prepare and submit notifications specified in 40 CFR Section 75.61, as applicable to the affected EGU(s). [40 CFR 60.5550(b)]

5.21.84 In each quarterly report the Permittee must include the following information, as applicable: (i) Each rolling average CO2 mass emissions rate for which the last (twelfth) operating month in a 12-operating-month compliance period falls within the calendar quarter. The Permittee must calculate each average CO2 mass emissions rate for the compliance period according to the procedures in 40 CFR Section 60.5540. The Permittee must report the dates (month and year) of the first and twelfth operating months in each compliance period for which the Permittee performed a CO2 mass emissions rate calculation. If there are no compliance periods that end in the quarter, the Permittee must include a statement to that effect; (ii) If one or more compliance periods end in the quarter, the Permittee must identify each operating month in the calendar quarter where the EGU violated the applicable CO2 emission standard; (iii) If one or more compliance periods end in the quarter and there are no violations for the affected EGU, the Permittee must include a statement indicating this in the report; (iv) The percentage of valid operating hours in each 12-operating-month compliance period described in 40 CFR Section 60.5540(a)(1)(i) (i.e., the total number of valid operating hours (as defined in 40 CFR Section 60.5540(a)(1)) in that period divided by the total number of operating hours in that period, multiplied by 100 percent); (v) Consistent with 40 CFR Section 60.5520, the CO2 emissions standard (as identified in 40 CFR pt. 60, subp. TTTT table 1 or 2) with which the affected EGU must comply; and (vi) Consistent with 40 CFR Section 60.5520, an indication whether or not the hourly gross or net energy output (Pgross/net) values used in the compliance determinations are based solely upon gross electrical load. [40 CFR 60.5555(a)(2)(i) - (vi)]

5.21.85 In the final quarterly report of each calendar year, the Permittee must include the following: (i) Consistent with 40 CFR Section 60.5520, gross energy output or net energy output sold to an electric grid, as applicable to the units of your emission standard, over the four quarters of the calendar year; and (ii) The potential electric output of the EGU. [40 CFR 60.5555(a)(3)(i) - (ii)]

5.21.86 The Permittee must submit all electronic reports required under 40 CFR Section 60.5555(a) using the Emissions Collection and Monitoring Plan System (ECMPS) Client Tool provided by the Clean Air Markets Division in the Office of Atmospheric Programs of EPA. [40 CFR 60.5555(b)]



5.21.87 The Permittee must meet all applicable reporting requirements and submit reports as required under 40 CFR pt. 75, subpart G. [40 CFR 60.5555(c)(1)]

5.21.88 The Permittee must begin submitting the quarterly electronic emissions reports described in 40 CFR Section 60.5555(c)(1) in accordance with 40 CFR Section 75.64(a), i.e., beginning with data recorded on and after the earlier of: (A) The date of provisional certification, as defined in 40 CFR Section 75.20(a)(3); or (B) 180 days after the date on which the EGU commences commercial operation (as defined in 40 CFR Section 72.2). [40 CFR 60.5555(c)(3)(i)(A) - (B)]

5.21.89 The reports required under 40 CFR Section 60.5555(a) and (c)(1) shall be submitted by: (1) The person appointed as the Designated Representative (DR) under 40 CFR Section 72.20; or (2) The person appointed as the Alternate Designated Representative (ADR) under 40 CFR Section 72.22; or (3) A person (or persons) authorized by the DR or ADR under 40 CFR Section 72.26 to make the required submissions. [40 CFR 60.5555(d)(1) - (3)]

5.21.90 The Permittee must maintain records of the information used to demonstrate compliance with 40 CFR pt. 60, subp. TTTT as specified in 40 CFR Section 60.7(b) and (f). (b)(1) The Permittee must follow the applicable recordkeeping requirements and maintain records as required under 40 CFR pt. 75, subpart F. (f) The Permittee must keep records of the calculations performed to assess compliance with each applicable CO2 mass emissions standard in 40 CFR pt. 60, subp. TTTT Table 1 or 2. [40 CFR 60.5560(a)(b)(1) & (f)]

5.21.91 Consistent with 40 CFR Section 60.5520, the Permittee must keep records of the applicable data recorded and calculations performed that were used to determine the affected EGU's gross or net energy output for each operating month. [40 CFR 60.5560(d)]

5.21.92 The Permittee must keep records of the calculations performed to determine the percentage of valid CO2 mass emission rates in each compliance period. [40 CFR 60.5560(e)]

5.21.93 Records must be in a form suitable and readily available for expeditious review. [40 CFR 60.5565(a)]

5.21.94 The Permittee must maintain each record for 3 years after the date of conclusion of each compliance period. [40 CFR 60.5565(b)]

5.21.95 The Permittee must maintain each record on site for at least 2 years after the date of each occurrence, measurement, maintenance, corrective action, report, or record, according to 40 CFR Section 60.7. Records that are accessible from a central location by a computer or other means that instantly provide



access at the site meet this requirement. The Permittee may maintain the records off site for the remaining year(s) as required by 40 CFR pt. 60, subp. TTTT. [40 CFR 60.5565(c)]

5.21.96 Notwithstanding any other provision of this chapter, certain parts of the general provisions in 40 CFR Sections 60.1 through 60.19, listed in 40 CFR pt. 60, subp. TTTT table 3, do not apply to the affected EGU. [40 CFR 60.5570]

5.21.97 Except as provided in subparts B and C, the provisions of this part apply to the owner or operator of any stationary source which contains an affected facility, the construction or modification of which is commenced after the date of publication in this part of any standard (or, if earlier, the date of publication of any proposed standard) applicable to that facility. [40 CFR 60.1(a), Minn. R. 7011.0050]

5.21.98 Any new or revised standard of performance promulgated pursuant to section 111(b) of the Act shall apply to the owner or operator of any stationary source which contains an affected facility, the construction or modification of which is commenced after the date of publication in this part of such new or revised standard (or, if earlier, the date of publication of any proposed standard) applicable to that facility. [40 CFR 60.1(b), Minn. R. 7011.0050]

5.21.99 In addition to complying with the provisions of this part, the owner or operator of an affected facility may be required to obtain an operating permit issued to stationary sources by an authorized State air pollution control agency or by the Administrator of the U.S. Environmental Protection Agency (EPA) pursuant to Title V of the Clean Air Act (Act) as amended November 15, 1990 (42 U.S.C. 7661). For more information about obtaining an operating permit see 40 CFR pt. 70. [40 CFR 60.1(c), Minn. R. 7011.0050]

5.21.100 The Permittee shall submit a notification of any physical or operational change to an existing facility which may increase the emission rate of any air pollutant to which a standard applies, unless that change is specifically exempted under an applicable subpart or in 40 CFR Section 60.14(e). This notice shall be postmarked 60 days or as soon as practicable before the change is commenced and shall include information describing the precise nature of the change, present and proposed emission control systems, productive capacity of the facility before and after the change, and the expected completion date of the change. The Administrator may request additional relevant information subsequent to this notice. [40 CFR 60.7(a)(4), Minn. R. 7019.0100, subp. 1]

5.21.101 Recordkeeping: The Permittee shall maintain records of the occurrence and duration of any startup, shutdown, or malfunction in the operation of an affected facility; any malfunction of the air pollution control equipment; or any periods during which a continuous monitoring system or monitoring device is inoperative. [40 CFR 60.7(b), Minn. R. 7019.0100, subp. 1]

5.21.102 The summary report form shall contain the information and be



in the format shown in figure 1 of 40 CFR Section 60.7 unless otherwise specified by the Administrator. One summary report form shall be submitted for each pollutant monitored at each affected facility. (1) If the total duration of excess emissions 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 form shall be submitted and the excess emission report described in 40 CFR Section 60.7(c) need not be submitted unless requested by the Administrator. (2) If the total duration of excess emissions 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, the summary report form and the excess emission report described in 40 CFR Section 60.7(c) shall both be submitted. [40 CFR 60.7(d), Minn. R. 7019.0100, subp. 1]

5.21.103 Notwithstanding the frequency of reporting requirements specified in 40 CFR Section 60.7(c), a Permittee who is required by an applicable subpart to submit excess emissions and monitoring systems performance reports (and summary reports) on a quarterly (or more frequent) basis may reduce the frequency of reporting for that standard to semiannual if the following conditions are met: (i) For 1 full year (e.g., 4 quarterly or 12 monthly reporting periods) the affected facility's excess emissions and monitoring systems reports submitted to comply with a standard under this part continually demonstrate that the facility is in compliance with the applicable standard; (ii) The Permittee continues to comply with all recordkeeping and monitoring requirements specified in this subpart and the applicable standard; and (iii) The Administrator does not object to a reduced frequency of reporting for the affected facility, as provided in 40 CFR Section 60.7(e)(2). [40 CFR 60.7(e)(1), Minn. R. 7019.0100, subp. 1]

5.21.104 The frequency of reporting of excess emissions and monitoring systems performance (and summary) reports may be reduced only after the Permittee notifies the Administrator in writing of his or her 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 required recordkeeping period prior to the intended change, including performance test results, monitoring data, and evaluations of a 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 60.7(e)(2), Minn. R. 7019.0100, subp. 1]

5.21.105 As soon as monitoring data indicate that the affected facility is not in compliance with any emission limitation or operating parameter specified in the applicable standard, the frequency of reporting shall revert to the frequency specified in the applicable standard, and the Permittee shall submit an excess emissions and monitoring systems performance report (and summary report, if required) at the next appropriate reporting period following the noncomplying event. After demonstrating compliance with the applicable standard for another full year, the Permittee may again request approval from the Administrator to reduce the frequency of reporting for that standard as provided for in 40 CFR Section 60.7(e)(1) and (e)(2). [40 CFR 60.7(e)(3), Minn. R. 7019.0100, subp. 1]

5.21.106 Recordkeeping: Maintain a file of all measurements, maintenance, reports and records for at least five years. 40 CFR Section 60.7(f) specifies two years. [40 CFR 60.7(f), Minn. R. 7019.0100, subp. 1]

5.21.107 If notification substantially similar to that in 40 CFR Section 60.7(a) is required by any other State or local agency, sending the Administrator a copy of that notification will satisfy the requirements of 40 CFR Section 60.7(a). [40 CFR 60.7(g), Minn. R. 7019.0100, subp. 1]

5.21.108 Individual subparts of this part may include specific provisions which clarify or make inapplicable the provisions set forth in this section. [40 CFR 60.7(h), Minn. R. 7019.0100, subp. 1]

5.21.109 The availability to the public of information provided to, or otherwise obtained by, the Administrator under this part shall be governed by 40 CFR pt. 2. (Information submitted voluntarily to the Administrator for the purposes of 40 CFR Sections 60.5 and 60.6 is governed by 40 CFR Sections 2.201 through 2.213 and not by 40 CFR Section 2.301.). [40 CFR 60.9]

5.21.110 The provisions of this part shall not be construed in any manner to preclude any State or political subdivision thereof from: (a) Adopting and enforcing any emission standard or limitation applicable to an affected facility, provided that such emission standard or limitation is not less stringent than the standard applicable to such facility. (b) Requiring the Permittee to obtain permits, licenses, or approvals prior to initiating construction, modification, or



operation of such facility. [40 CFR 60.10]

5.21.111 Compliance with standards in this part, other than opacity standards, shall be determined in accordance with performance tests established by 40 CFR Section 60.8, unless otherwise specified in the applicable standard. [40 CFR 60.11(a), Minn. R. 7017.2015]

5.21.112 Compliance with opacity standards in this part shall be determined by conducting observations in accordance with Method 9 in 40 CFR pt. 60, appendix A, any alternative method that is approved by the Administrator, or as provided in 40 CFR Section 60.11(e)(5). For purposes of determining initial compliance, the minimum total time of observations shall be 3 hours (30 6-minute averages) for the performance test or other set of observations (meaning those fugitive-type emission sources subject only to an opacity standard). [40 CFR 60.11(b), Minn. R. 7017.2015]

5.21.113 The opacity standards set forth in this part shall apply at all times except during periods of startup, shutdown, malfunction, and as otherwise provided in the applicable standard. [40 CFR 60.11(c), Minn. R. 7017.2015]

5.21.114 At all times, including periods of startup, shutdown, and malfunction, the Permittee shall, to the extent practicable, maintain and operate any affected facility including associated air pollution control equipment in a manner consistent with good air pollution control practice for minimizing emissions. Determination of whether acceptable operating 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, opacity observations, review of operating and maintenance procedures, and inspection of the source. [40 CFR 60.11(d), Minn. R. 7017.2015]

5.21.115 For the purpose of demonstrating initial compliance, conduct opacity observations concurrently with the initial performance test required in 40 CFR Section 60.8 and include the results in the test report, pursuant to the conditions described in 40 CFR Section 60.11(e)(1)-(8). [40 CFR 60.11(e), Minn. R. 7017.2015]

5.21.116 Special provisions set forth under an applicable subpart shall supersede any conflicting provisions in 40 CFR Section 60.11(a) through (e). [40 CFR 60.11(f), Minn. R. 7017.2015]

5.21.117 For the purpose of submitting compliance certifications or establishing whether or not a person has violated or is in violation of any standard in this part, nothing in this part shall preclude the use, including the exclusive use, of any credible evidence or information, relevant to whether a source would have been in compliance with applicable requirements if the appropriate performance or compliance test or procedure had been performed. [40 CFR 60.11(g), Minn. R. 7017.2015]

5.21.118 No owner or operator shall build, erect, install, or use any article, machine, equipment or process, the use of which conceals an emission which would otherwise constitute a violation of an applicable standard. [40 CFR 60.12, Minn. R.



7011.0050]

5.21.119 CEMS QA/QC: The owner or operator of an affected facility is subject to the performance specifications listed in 40 CFR pt. 60, Appendix B and shall operate, calibrate, and maintain each CEMS according to the QA/QC procedures in 40 CFR pt. 60, Appendix F as amended and maintain a written QA/QC program available in a form suitable for inspection. [40 CFR 60.13(a), 40 CFR pt. 60, Appendix F, Minn. R. 7017.1010]

5.21.120 All continuous monitoring systems and monitoring devices required under 40 CFR 60, including CEMS and COMS shall be installed and operational prior to conducting performance tests under 40 CFR Section 60.8. [40 CFR 60.13(b), Minn. R. 7017.1010]

5.21.121 The Permittee shall conduct a performance evaluation of the CEMS during any performance test required under 40 CFR Section 60.8 or within 30 days thereafter in accordance with the applicable performance specification in 40 CFR pt. 60, appendix B. The Permittee shall conduct CEMS performance evaluations at such other times as may be required by the Administrator under section 114 of the Act. [40 CFR 60.13(c), Minn. R. 7017.1010]

5.21.122 The Permittee must check the zero (or low level value between 0 and 20 percent of span value) and span (50 to 100 percent of span value) calibration drifts at least once each operating day in accordance with a written procedure. The zero and span must, at a minimum, be adjusted whenever either the 24-hour zero drift or the 24-hour span drift exceeds two times the limit of the applicable performance specification in 40 CFR pt. 60, appendix B. The system must allow the amount of the excess zero and span drift to be recorded and quantified whenever specified. The Permittee must check the zero and upscale (span) calibration drifts at least once daily. For a particular COMS, the acceptable range of zero and upscale calibration materials is defined in the applicable version of PS-1 in 40 CFR pt. 60, appendix B. For a COMS, the optical surfaces, exposed to the effluent gases, must be cleaned before performing the zero and upscale drift adjustments, except for systems using automatic zero adjustments. The optical surfaces must be cleaned when the cumulative automatic zero compensation exceeds 4 percent opacity. [40 CFR 60.13(d)(1), Minn. R. 7017.1010]

5.21.123 Except for system breakdowns, repairs, calibration checks, and zero and span adjustments required under 40 CFR Section 60.13(d), all continuous monitoring systems shall be in continuous operation and shall meet minimum frequency of operation requirements as follows: All continuous monitoring systems referenced by 40 CFR Section 60.13(c) for measuring emissions, except opacity, shall complete a minimum of one cycle of operation (sampling, analyzing, and data recording) for each successive 15-minute period. [40 CFR 60.13(e), Minn. R. 7017.1010]



5.21.124 All continuous monitoring systems or monitoring devices shall be installed such that representative measurements of emissions or process parameters from the affected facility are obtained. Additional procedures for location of continuous monitoring systems contained in the applicable Performance Specifications of 40 CFR pt. 60, appendix B shall be used. [40 CFR 60.13(f), Minn. R. 7017.1010]

5.21.125 When the effluents from a single affected facility or two or more affected facilities subject to the same emission standards are combined before being released to the atmosphere, the Permittee may install applicable continuous monitoring systems on each effluent or on the combined effluent. When the affected facilities are not subject to the same emission standards, separate continuous monitoring systems shall be installed on each effluent. When the effluent from one affected facility is released to the atmosphere through more than one point, the Permittee shall install an applicable continuous monitoring system on each separate effluent unless the installation of fewer systems is approved by the Administrator. When more than one continuous monitoring system is used to measure the emissions from one affected facility (e.g., multiple breechings, multiple outlets), the Permittee shall report the results as required from each continuous monitoring system. [40 CFR 60.13(g), Minn. R. 7017.1010]

5.21.126 For continuous monitoring systems other than opacity, 1-hour averages shall be computed as specified in 40 CFR Section 60.13(h)(2)(i) through (ix), except that the provisions pertaining to the validation of partial operating hours are only applicable for affected facilities that are required by the applicable subpart to include partial hours in the emission calculations. [40 CFR 60.13(h)(2), Minn. R. 7017.1010]

5.21.127 All excess emissions shall be converted into units of the standard using the applicable conversion procedures specified in the applicable subpart. After conversion into units of the standard, the data may be rounded to the same number of significant digits used in the applicable subpart to specify the emission limit. [40 CFR 60.13(h)(3), Minn. R. 7017.1010]

5.21.128 After receipt and consideration of written application, the Administrator may approve alternatives to any monitoring procedures or requirements of this part including, but not limited to the requirements listed at 40 CFR Section 60.13(i)(1) through (9). [40 CFR 60.13(i), Minn. R. 7017.1010]

5.21.129 An alternative to the relative accuracy (RA) test specified in Performance Specification 2 of 40 CFR pt. 60, appendix B may be requested as described in 40 CFR Section 60.13(j)(1) and (j)(2). [40 CFR 60.13(j), Minn. R. 7017.1010]

5.21.130 Except as provided under 40 CFR Section 60.14(e) and (f), any physical or operational change to an existing facility which results in an increase in the emission rate to the atmosphere of any pollutant to which a standard applies shall be considered a modification within the meaning of section 111



of the Act. Upon modification, an existing facility shall become an affected facility for each pollutant to which a standard applies and for which there is an increase in the emission rate to the atmosphere. [40 CFR 60.14(a), Minn. R. 7011.0050]

5.21.131 The addition of an affected facility to a stationary source as an expansion to that source or as a replacement for an existing facility shall not by itself bring within the applicability of this part any other facility within that source. [40 CFR 60.14(c), Minn. R. 7011.0050]

5.21.132 The following shall not, by themselves, be considered modifications under this part: (1) Maintenance, repair, and replacement which the Administrator determines to be routine for a source category, subject to the provisions of 40 CFR Section 60.14(c) and 40 CFR Section 60.15. (2) An increase in production rate of an existing facility, if that increase can be accomplished without a capital expenditure on that facility. (3) An increase in the hours of operation. (4) Use of an alternative fuel or raw material if, prior to the date any standard under this part becomes applicable to that source type, as provided by 40 CFR Section 60.1, the existing facility was designed to accommodate that alternative use. A facility shall be considered to be designed to accommodate an alternative fuel or raw material if that use could be accomplished under the facility's construction specifications as amended prior to the change. Conversion to coal required for energy considerations, as specified in section 111(a)(8) of the Act, shall not be considered a modification. (5) The addition or use of any system or device whose primary function is the reduction of air pollutants, except when an emission control system is removed or is replaced by a system which the Administrator determines to be less environmentally beneficial. (6) The relocation or change in ownership of an existing facility. [40 CFR 60.14(e), Minn. R. 7011.0050]

5.21.133 Special provisions set forth under an applicable subpart of this part shall supersede any conflicting provisions of this section. [40 CFR 60.14(f), Minn. R. 7011.0050]

5.21.134 Within 180 days of the completion of any physical or operational change subject to the control measures specified in 40 CFR Section 60.14(a), compliance with all applicable standards must be achieved. [40 CFR 60.14(g), Minn. R. 7011.0050]

5.21.135 No physical change, or change in the method of operation, at an existing electric utility steam generating unit shall be treated as a modification for the purposes of this section provided that such change does not increase the maximum hourly emissions of any pollutant regulated under this section above the maximum hourly emissions achievable at that unit during the 5 years prior to the change. [40 CFR 60.14(h), Minn.



R. 7011.0050]

5.21.136 Repowering projects that are awarded funding from the Department of Energy as permanent clean coal technology demonstration projects (or similar projects funded by EPA) are exempt from the requirements of this section provided that such change does not increase the maximum hourly emissions of any pollutant regulated under this section above the maximum hourly emissions achievable at that unit during the five years prior to the change. [40 CFR 60.14(i), Minn. R. 7011.0050]

5.21.137 Repowering projects that qualify for an extension under section 409(b) of the Clean Air Act are exempt from the requirements of this section, provided that such change does not increase the actual hourly emissions of any pollutant regulated under this section above the actual hourly emissions achievable at that unit during the 5 years prior to the change. This exemption shall not apply to any new unit that: (i) Is designated as a replacement for an existing unit; (ii) Qualifies under section 409(b) of the Clean Air Act for an extension of an emission limitation compliance date under section 405 of the Clean Air Act; and (iii) Is located at a different site than the existing unit. [40 CFR 60.14(j), Minn. R. 7011.0050]

5.21.138 The installation, operation, cessation, or removal of a temporary clean coal technology demonstration project is exempt from the requirements of this section. A temporary clean coal control technology demonstration project, for the purposes of this section is a clean coal technology demonstration project that is operated for a period of 5 years or less, and which complies with the State implementation plan for the State in which the project is located and other requirements necessary to attain and maintain the national ambient air quality standards during the project and after it is terminated. [40 CFR 60.14(k), Minn. R. 7011.0050]

5.21.139 The reactivation of a very clean coal-fired electric utility steam generating unit is exempt from the requirements of this section. [40 CFR 60.14(l), Minn. R. 7011.0050]

5.21.140 An existing facility, upon reconstruction, becomes an affected facility, irrespective of any change in emission rate. [40 CFR 60.15(a), Minn. R. 7011.0050]

5.21.141 Reconstruction means the replacement of components of an existing facility to such an extent that: (1) The fixed capital cost of the new components exceeds 50 percent of the fixed capital cost that would be required to construct a comparable entirely new facility, and (2) It is technologically and economically feasible to meet the applicable standards set forth in this part. [40 CFR 60.15(b), Minn. R. 7011.0050]

5.21.142 Fixed capital cost means the capital needed to provide all the depreciable components. [40 CFR 60.15(c), Minn. R.



7011.0050]

5.21.143 If a Permittee proposes to replace components, and the fixed capital cost of the new components exceeds 50 percent of the fixed capital cost that would be required to construct a comparable entirely new facility, the Permittee shall notify the Administrator of the proposed replacements. The notice must be postmarked 60 days (or as soon as practicable) before construction of the replacements is commenced and must include the following information: (1) Name and address of the owner or operator. (2) The location of the existing facility. (3) A brief description of the existing facility and the components which are to be replaced. (4) A description of the existing air pollution control equipment and the proposed air pollution control equipment. (5) An estimate of the fixed capital cost of the replacements and of constructing a comparable entirely new facility. (6) The estimated life of the existing facility after the replacements. (7) A discussion of any economic or technical limitations the facility may have in complying with the applicable standards of performance after the proposed replacements. [40 CFR 60.15(d), Minn. R. 7011.0050]

5.21.144 Additional requirements for Combustion Turbine #1 are located at EQUI 16. Additional requirements for Duct Burners (Combustion Turbine #1) are located at EQUI 17. [Minn. R. 7007.0800, 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.


TFAC 1 01300098 Mankato Energy Center LLC

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 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)]

6.1.3 The Permittee shall submit a compliance certification : Due



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

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. [40 CFR 60.7(c), 40 CFR 75.64, Minn. R. 7017.1110, subp. 1-2]


6.2.1 The Permittee shall conduct linearity and leak check : Due after Startup of Monitor Date quarterly in accordance with procedures in 40 CFR pt. 75, Appendix B, Sections 2.2.1 and 2.2.2, and Appendix A, Section 6.2. This means once every calendar quarter in which there are at least 168 unit operating hours. Perform a leak check at least once during each QA operating quarter. [40 CFR pt. 75, Appendix B, 2.2]


6.3.1 The Permittee shall conduct CEMS cylinder gas audit (CGA) : Due after CEMS Certification Test Date quarterly but no more than three quarters in succession. A CGA is not required during any calendar quarter in which a RATA was performed. [40 CFR pt. 60, Appendix F, 5.1.3]

6.3.2 The Permittee shall conduct CEMS relative accuracy test audit (RATA) : Due after CEMS Certification Test Date annually meaning by the end of every one of four calendar quarters. [40 CFR pt. 60, Appendix F, 5.1.1]

EQUI 7 EU005 Auxiliary Boiler

6.4.1 PM < 10 micron : The Permittee shall conduct an initial performance test : Due 180 calendar days after Permit Issuance Date to measure emissions. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2025, subp. 2, using EPA Reference Method 201A and 202, or other method approved by MPCA in the performance test plan approval. [Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

6.4.2 Total Particulate Matter : The Permittee shall conduct an initial performance test : Due 180 calendar days after Permit Issuance Date to measure emissions. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2025, subp. 2, using EPA Reference Method 5 and 202, or other method approved by MPCA in the performance test plan



approval. [Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

6.4.3 Sulfur Dioxide : The Permittee shall conduct an initial performance test : Due 180 calendar days after Permit Issuance Date to measure emissions. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2025, subp. 2, using EPA Reference Method 6C, or other method approved by MPCA in the performance test plan approval. [Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

6.4.4 Volatile Organic Compounds : The Permittee shall conduct an initial performance test : Due 180 calendar days after Permit Issuance Date to measure emissions. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2025, subp. 2, using EPA Reference Method 25A, or other method approved by MPCA in the performance test plan approval. [Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

6.4.5 Carbon Monoxide : The Permittee shall conduct a performance test : Due before 07/13/2021 every 60 months to measure emissions. The first test is due by the date specified and all subsequent tests are due by the end of each 60-month period following that date. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2025, subp. 2, using EPA Reference Method 10, or other method approved by MPCA in the performance test plan approval. Testing conducted during the 60 days prior to the performance test due date satisfies the performance test due date, and will not reset the test due date for future testing as required: 1) by this permit; 2) by the most recently approved Performance Test Frequency Plan; or 3) within a Notice of Compliance letter. Testing conducted more than two months prior to the performance test due date satisfies this test due date requirement and will reset the performance test due date. [Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

6.4.6 Nitrogen Oxides : The Permittee shall conduct a performance test : Due before 07/13/2021 every 60 months to measure emissions. The first test is due by the date specified and all subsequent tests are due by the end of each 60-month period following that date. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2025, subp. 2, using EPA Reference Method 7E, or other method approved by MPCA in the performance test plan approval. Testing conducted during the 60 days prior to the performance test due date satisfies the performance test due date, and will not reset the test due date for future testing as required: 1) by this permit; 2) by the most recently approved Performance Test Frequency



Plan; or 3) within a Notice of Compliance letter. Testing conducted more than two months prior to the performance test due date satisfies this test due date requirement and will reset the performance test due date. [Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

6.4.7 PM < 10 micron: The Permittee shall submit a test frequency plan for PM10: Due 60 calendar days after Initial Performance Test Date for PM10 emissions. The plan shall specify a testing frequency based on the test data and MPCA guidance. Future performance tests based on 12-month, 36-month, or 60-month intervals, or as applicable, shall be required upon written approval of the MPCA. [Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

6.4.8 Total Particulate Matter: The Permittee shall submit a test frequency plan for Total Particulate Matter: Due 60 calendar days after Initial Performance Test Date for PM emissions. The plan shall specify a testing frequency based on the test data and MPCA guidance. Future performance tests based on 12-month, 36-month, or 60-month intervals, or as applicable, shall be required upon written approval of the MPCA. [Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

6.4.9 Sulfur Dioxide: The Permittee shall submit a test frequency plan for Sulfur Dioxide: Due 60 calendar days after Initial Performance Test Date for SO2 emissions. The plan shall specify a testing frequency based on the test data and MPCA guidance. Future performance tests based on 12-month, 36-month, or 60-month intervals, or as applicable, shall be required upon written approval of the MPCA. [Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

6.4.10 Volatile Organic Compounds: The Permittee shall submit a test frequency plan for Volatile Organic Compounds: Due 60 calendar days after Initial Performance Test Date for VOC emissions. The plan shall specify a testing frequency based on the test data and MPCA guidance. Future performance tests based on 12-month, 36-month, or 60-month intervals, or as applicable, shall be required upon written approval of the MPCA. [Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]


6.5.1 The Permittee shall conduct an initial performance test : Due 180 calendar days after Initial Startup Date of first firing and again prior to obtaining a new permit to verify compliance with the heat rate limit. [Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]


6.6.1 The Permittee shall conduct linearity and leak check : Due after



Startup of Monitor Date quarterly in accordance with procedures in 40 CFR pt. 75, Appendix B, Sections 2.2.1 and 2.2.2, and Appendix A, Section 6.2. This means once every calendar quarter in which there are at least 168 unit operating hours. Perform a leak check at least once during each QA operating quarter. [40 CFR pt. 75, Appendix B, 2.2]


6.7.1 The Permittee shall submit start-up notification : Due 10 working days after Startup of Monitor Date. [Minn. R. 7007.0800, subp. 2]

6.7.2 The Permittee shall conduct CEMS cylinder gas audit (CGA) : Due after CEMS Certification Test Date quarterly but no more than three quarters in succession. A CGA is not required during any calendar quarter in which a RATA was performed. [40 CFR pt. 60, Appendix F, 5.1.3]

6.7.3 The Permittee shall conduct CEMS relative accuracy test audit (RATA) : Due after CEMS Certification Test Date annually meaning by the end of every one of four calendar quarters. [40 CFR pt. 60, Appendix F, 5.1.1]


6.8.1 PM < 10 micron : The Permittee shall conduct a performance test : Due before 09/30/2016 every 60 months to measure emissions at Natural Gas base load with duct burner operation. The first test is due by the date specified and all subsequent tests are due by the end of each 60-month period following that date. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2025, subp. 2, using EPA Reference Method 201A and 202, or other method approved by MPCA in the performance test plan approval. Testing while combusting distillate fuel oil at base load is only required if EQUI 5 combusts distillate fuel oil for more than 50 hours in any 12-month period during the 60 months prior to the required performance test. Testing conducted during the 60 days prior to the performance test due date satisfies the performance test due date, and will not reset the test due date for future testing as required: 1) by this permit; 2) by the most recently approved Performance Test Frequency Plan; or 3) within a Notice of Compliance letter. Testing conducted more than two months prior to the performance test due date satisfies this test due date requirement and will reset the performance test due date. [Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

6.8.2 PM < 2.5 micron : The Permittee shall conduct a performance test : Due before 06/23/2018 every 60 months to measure



emissions at Natural Gas base load with duct burner operation. The first test is due by the date specified and all subsequent tests are due by the end of each 60-month period following that date. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2025, subp. 2, using EPA Reference Method 201A and 202, or other method approved by MPCA in the performance test plan approval. Testing while combusting distillate fuel oil at base load is only required if EQUI 5 combusts distillate fuel oil for more than 50 hours in any 12-month period during the 60 months prior to the required performance test. Testing conducted during the 60 days prior to the performance test due date satisfies the performance test due date, and will not reset the test due date for future testing as required: 1) by this permit; 2) by the most recently approved Performance Test Frequency Plan; or 3) within a Notice of Compliance letter. Testing conducted more than two months prior to the performance test due date satisfies this test due date requirement and will reset the performance test due date. [Minn. R. 7007.0800, subp. 2, Minn. R. 7017.2020, subp. 1]

6.8.3 Total Particulate Matter : The Permittee shall conduct a performance test : Due before 09/30/2016 every 60 months to measure emissions at Natural Gas base load with duct burner operation. The first test is due by the date specified and all subsequent tests are due by the end of each 60-month period following that date. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2025, subp. 2, using EPA Reference Method 5 and 202, or other method approved by MPCA in the performance test plan approval. Testing while combusting distillate fuel oil at base load is only required if EQUI 5 combusts distillate fuel oil for more than 50 hours in any 12-month period during the 60 months prior to the required performance test. Testing conducted during the 60 days prior to the performance test due date satisfies the performance test due date, and will not reset the test due date for future testing as required: 1) by this permit; 2) by the most recently approved Performance Test Frequency Plan; or 3) within a Notice of Compliance letter. Testing conducted more than two months prior to the performance test due date satisfies this test due date requirement and will reset the performance test due date. [Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

6.8.4 Volatile Organic Compounds : The Permittee shall conduct a performance test : Due before 09/30/2016 every 60 months to measure emissions. The first test is due by the date specified and all subsequent tests are due by the end of each 60-month



period following that date. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2025, subp. 2, using EPA Reference Method 25A, or other method approved by MPCA in the performance test plan approval. Testing while combusting distillate fuel oil is only required if EQUI 5 combusts distillate fuel oil for more than 50 hours in any 12-month period during the 60 months prior to the required performance test. Testing conducted during the 60 days prior to the performance test due date satisfies the performance test due date, and will not reset the test due date for future testing as required: 1) by this permit; 2) by the most recently approved Performance Test Frequency Plan; or 3) within a Notice of Compliance letter. Testing conducted more than two months prior to the performance test due date satisfies this test due date requirement and will reset the performance test due date. [Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

6.8.5 Hexane : The Permittee shall conduct a performance test : Due before 09/30/2016 every 60 months to verify the emission factor of hexane (in lb/mmBtu). The first test is due by the date specified and all subsequent tests are due by the end of each 60-month period following that date. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2025, subp. 2, using EPA Reference Method 18, 320, or other method approved by MPCA in the performance test plan approval. The tests shall be conducted while combusting natural gas at 90 to 100 percent load (base load with EQUI 6). Testing conducted during the 60 days prior to the performance test due date satisfies the performance test due date, and will not reset the test due date for future testing as required: 1) by this permit; 2) by the most recently approved Performance Test Frequency Plan; or 3) within a Notice of Compliance letter. Testing conducted more than two months prior to the performance test due date satisfies this test due date requirement and will reset the performance test due date. [Minn. R. 7011.7000, Minn. R. 7017.2020, subp. 1, Title I Condition: Avoid major source under 40 CFR 63.2]

6.8.6 Formaldehyde : The Permittee shall conduct a performance test : Due before 09/30/2016 every 30 months to verify the emission factor of formaldehyde (in lb/mmBtu). The first test is due by the date specified and all subsequent tests are due by the end of each 30-month period following that date. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2025, subp. 2, using EPA Reference Method 18, 320, or other method approved by MPCA in the performance test plan approval. The tests shall be conducted while



combusting natural gas under the following conditions: 1. 15 to 30 percent load; 2. 60 to 70 percent load; 3. 90 to 100 percent load (base load with EQUI 6). In lieu of testing at 30-month intervals, the Permittee has the option of formaldehyde emission factor verification testing at 60-month intervals while combusting natural gas if the Permittee uses the maximum (and not the average) one-hour emission rate of the three formaldehyde emission factor test runs for operations at each operating load. The Permittee also has the option of submitting a test frequency plan as described under Subject Item STRU 14 of this permit to reduce natural gas formaldehyde test frequency. Testing conducted during the 60 days prior to the performance test due date satisfies the performance test due date, and will not reset the test due date for future testing as required: 1) by this permit; 2) by the most recently approved Performance Test Frequency Plan; or 3) within a Notice of Compliance letter. Testing conducted more than two months prior to the performance test due date satisfies this test due date requirement and will reset the performance test due date. [Minn. R. 7011.7000, Minn. R. 7017.2020, subp. 1, Title I Condition: Avoid major source under 40 CFR 63.2]


6.9.1 The Permittee shall submit a report : Due semiannually and each report must be postmarked by the 30th day following the end of each 6-month period as required under 40 CFR Section 60.7(c). [40 CFR 60.4395]

6.9.2 The Permittee shall submit a report : Due by the end of each calendar quarter after accumulating the first 12-operating months for the affected EGU, for the calendar quarter that includes the twelfth operating month no later than 30 days after the end of that quarter. Thereafter, the Permittee must submit a report for each subsequent calendar quarter, no later than 30 days after the end of the quarter. [40 CFR 60.5555(a)(1)]

6.9.3 The Permittee shall submit a notification of the date construction began : Due 30 calendar days after Date of Construction Start (or reconstruction as defined under 40 CFR Section 60.15) of an affected facility. The notification shall be postmarked no later than 30 days after such date. This requirement shall not apply in the case of mass-produced facilities which are purchased in completed form. [40 CFR 60.7(a)(1), Minn. R. 7019.0100, subp. 1]



6.9.4 The Permittee shall submit a notification of the actual date of initial startup : Due 15 calendar days after Initial Startup Date. [40 CFR 60.7(a)(3), Minn. R. 7019.0100, subp. 1]

6.9.5 The Permittee shall submit a notification : Due 30 calendar days before Startup of Monitor Date of the continuous monitoring system (CMS) in accordance with 40 CFR Section 60.13(c). [40 CFR 60.13(c), 40 CFR 60.7(a)(5), Minn. R. 7019.0100, subp. 1]

6.9.6 The Permittee shall submit a notification : Due 30 calendar days before Opacity Observation Date required by 40 CFR Section 60.11(e)(1). The notification shall also include, if appropriate, a request for the Administrator to provide a visible emissions reader during a performance test. [40 CFR 60.7(a)(6), Minn. R. 7019.0100, subp. 1]

6.9.7 The Permittee shall submit excess emission/downtime report : Due by the end of each calendar half-year, except when: more frequent reporting is specifically required by an applicable subpart; or the Administrator, on a case-by-case basis, determines that more frequent reporting is necessary to accurately assess the compliance status of the source. All reports shall be postmarked by the 30th day following the end of each six-month period and include the information in 40 CFR Section 60.7(c)(1) through (4). [40 CFR 60.7(c), Minn. R. 7019.0100, subp. 1]

6.9.8 PM < 10 micron : The Permittee shall conduct an initial performance test : Due 180 calendar days after Initial Startup Date to measure emissions at base load with duct burners. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2025, subp. 2, using EPA Reference Method 201A and 202, or other method approved by MPCA in the performance test plan approval. [Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

6.9.9 PM < 2.5 micron : The Permittee shall conduct an initial performance test : Due 180 calendar days after Initial Startup Date to measure emissions at base load with duct burners. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2025, subp. 2, using EPA Reference Method 201A and 202, or other method approved by MPCA in the performance test plan approval. [Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

6.9.10 Total Particulate Matter : The Permittee shall conduct an initial performance test : Due 180 calendar days after Initial Startup Date to measure emissions at base load with duct burners. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2025, subp. 2, using EPA Reference Method 5 and 202, or other method approved by MPCA in the performance test plan approval. [Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

6.9.11 Volatile Organic Compounds : The Permittee shall conduct an initial performance test : Due 180 calendar days after Initial Startup Date to measure emissions. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2025, subp. 2, using EPA Reference Method 25A, or other



method approved by MPCA in the performance test plan approval. [Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

6.9.12 Hexane : The Permittee shall conduct an initial performance test : Due 180 calendar days after Initial Startup Date to verify the emission factor of hexane (in lb/mmBtu). The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2025, subp. 2, using EPA Reference Method 18, 320, or other method approved by MPCA in the performance test plan approval. Tests shall be conducted while combusting natural gas at 90 to 100 percent load (base load with EQUI 17). [Minn. R. 7011.7000, Minn. R. 7017.2020, subp. 1, Title I Condition: Avoid major source under 40 CFR 63.2]

6.9.13 Formaldehyde : The Permittee shall conduct an initial performance test : Due 180 calendar days after Initial Startup Date to verify the emission factor of formaldehyde (in lb/mmBtu). The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2025, subp. 2, using EPA Reference Method 18, 320, or other method approved by MPCA in the performance test plan approval. The tests shall be conducted while combusting natural gas under the following conditions: 1. 15 to 30 percent load; 2. 60 to 70 percent load; 3. 90 to 100 percent load (base load with EQUI 17). [Minn. R. 7011.7000, Minn. R. 7017.2020, subp. 1, Title I Condition: Avoid major source under 40 CFR 63.2]

6.9.14 PM < 10 micron : The Permittee shall submit a test frequency plan : Due 60 calendar days after Initial Performance Test Date for PM10 emissions. The plan shall specify a testing frequency based on the test data and MPCA guidance. Future performance tests based on 12-month, 36-month, or 60-month intervals, or as applicable, shall be required upon written approval of the MPCA. [Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

6.9.15 PM < 2.5 micron : The Permittee shall submit a test frequency plan : Due 60 calendar days after Initial Performance Test Date for PM2.5 emissions. The plan shall specify a testing frequency based on the test data and MPCA guidance. Future performance tests based on 12-month, 36-month, or 60-month intervals, or as applicable, shall be required upon written approval of the MPCA. [Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

6.9.16 Total Particulate Matter : The Permittee shall submit a test frequency plan : Due 60 calendar days after Initial Performance Test Date for PM emissions. The plan shall specify a testing frequency based on the test data and MPCA guidance. Future performance tests based on 12-month, 36-month, or 60-month intervals, or as applicable, shall be required upon written approval of the MPCA. [Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]



6.9.17 Volatile Organic Compounds : The Permittee shall submit a test frequency plan : Due 60 calendar days after Initial Performance Test Date for VOC emissions. The plan shall specify a testing frequency based on the test data and MPCA guidance. Future performance tests based on 12-month, 36-month, or 60-month intervals, or as applicable, shall be required upon written approval of the MPCA. [Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

6.9.18 Hexane : The Permittee shall submit a test frequency plan : Due 60 calendar days after Initial Performance Test Date for hexane emission factor. The plan shall specify a testing frequency based on the test data and MPCA guidance. Future performance tests based on 12-month, 36-month, or 60-month intervals, or as applicable, shall be required upon written approval of the MPCA. [Minn. R. 7011.7000, Minn. R. 7017.2020, subp. 1, Title I Condition: Avoid major source under 40 CFR 63.2]

6.9.19 Formaldehyde : The Permittee shall submit a test frequency plan : Due 60 calendar days after Initial Performance Test Date for formaldehyde emission factor. The plan shall specify a testing frequency based on the test data and MPCA guidance. Future performance tests based on 12-month, 36-month, or 60-month intervals, or as applicable, shall be required upon written approval of the MPCA. [Minn. R. 7011.7000, Minn. R. 7017.2020, subp. 1, Title I Condition: Avoid major source under 40 CFR 63.2]

6.9.20 The Permittee shall submit a notification : Due within 30 days of the end of the shakedown period for EQUI 16. The shakedown period shall be the earlier of 180 days after initial startup of EQUI 16, or 60 days after achieving maximum production of EQUI 16, or submittal of successful compliance test and CEMS certification reports for EQUI 16. [Minn. R. 7007.0800, subp. 2]


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(I) Individual emissions units at a stationary source, each of which have a potential to emit the following pollutants in amounts less than: (1) 4,000 lb/yr of CO (2) 2,000 lb/yr of NOx, SO2, PM, PM10, VOC & ozone; and (3) 1,000 tpy of CO2e Fire Pump Diesel Fuel Tank (360 gal) Natural Gas Condensate Tank - CT1 (45 gal) Natural Gas Condensate Tank - CT2 (45 gal) No. 2 Distillate Oil Storage Tank (350,000 gal)

No standards of performance (Fire Pump Tank, NG Condensate Tanks CT1 & CT2) (Minn. R. 7011.1505, subp. 3.A)

Keep records of type of petroleum liquid stored, of the typical Reid vapor pressure, dates of storage and withdrawals and date on which the storage vessel is empty (No. 2 Distillate Oil Storage Tank) (Minn. R. 7011.1505, subp. 3.C, Minn. R. 7011.1510, subp. 1.A)


Appendix B: Modeling Parameters

UTM Coordinates NOX CO SO2 PM10 Base

Eleva-tion

Stack Height

Stack Temp

Exit Velo-city

Stack Dia-

meter Model Stack Stack Description Easting Northing

Emission Rate

Emission Rate

Emission Rate

Emission Rate

ID (m) (m) (g/s) (g/s) (g/s) (g/s) (m) (m) (K) (m/s) (m)

STRU 14

Combustion Turbine #2 & Duct Burners #2 (8-hr CO) 419,926.3 4,894,472.1

26.53 153.205

12.193 9.173 242.30 60.96 344.26 12.27 5.79

STRU 14

Combustion Turbine #2 & Duct Burners #2 (1-hr CO) 419,926.3 4,894,472.1 475.138 242.30 60.96 344.26 12.27 5.79

STRU 17 Auxiliary Boiler 419,906.4 4,894,445.4 0.318 0.529 0.010 0.071 242.30 30.48 436.00 9.75 1.22

STRU 20 Combustion Turbine #1 & Duct Burners #1 419,929.0 4,894,539.4 24.19 --- --- --- 242.30 60.96 344.26 11.98 5.79

STRU 22 Bath Heater 419,931.1 4,894,443.7 0.035 --- --- --- 242.30 7.62 762.59 3.51 0.51


Appendix C: Acid Rain Permit Application

United States Environmental Protection Agency OMB No. 2060-0258

Acid Rain Program Approval expires 11/30/2012

Acid Rain Permit Application

STEP 1

Identify the facility name, State, and plant (ORIS) code.

For more information, see instructions and 40 CFR 72.30 and 72.31.

This submission is: □ New ■ Revised □ for ARP permit renewal

STEP 2

Enter the unit ID# for every affected unit at the affected source in column "a."

Facility (Source) Name: Mankato Energy

Center

State: Minnesota

Plant Code: 56104

a b

Unit ID# Unit Will Hold Allowances in Accordance with 40 CFR 72.9(c)(1)

CT-1 Yes

CT-2 Yes

Yes

Yes

Yes

Yes

Yes

Yes

Yes

Yes

Yes

Yes

Yes

Yes

Yes

Yes

Yes

Yes

Facility (Source) Name (from STEP 1): Mankato Energy Center

STEP 3

Read the standard requirements.

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 source or unit, as appropriate, 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 source's compliance account (after deductions under 40 CFR 73.34(c)), not less than the total annual emissions of sulfur dioxide for the previous calendar year from the affected units at the source; 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).


Sulfur Dioxide Requirements, Cont'd.

STEP 3, Cont'd. (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) 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 an exemption under 40 CFR 72.7 or 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 source 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 source 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;


STEP 3, Cont'd.

Recordkeeping and Reporting Requirements, Cont'd.

(ii) All emissions monitoring information, in accordance with 40 CFR part 75, provided that to the extent that 40 CFR part 75 provides 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 an 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. (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 an exemption under 40 CFR 72.7 or 72.8 shall be construed as:

Facility (Source) Name (from Mankato Energy Center c:..:,r .

Name Heidi M. Whidden

STEP 3, Cont’d.

STEP 4 Read the certification statement, sign, and date.

(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 source can hold; provided, that the number of allowances held by the source 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.

Certification

I am authorized to make this submission on behalf of the owners and operators of the affected source or affected units for which the submission is made. I certify under penalty of law that I have personally examined, and am familiar with, the statements and information submitted in this document and all its attachments. Based on my inquiry of those individuals with primary responsibility for obtaining the information, I certify that the statements and information are to the best of my knowledge and belief true, accurate, and complete. I am aware that there are significant penalties for submitting false statements and information or omitting required statements and information, including the possibility of fine or imprisonment.

Appendix D: Transport Rule (TR) Trading Program Title V Requirements

Description of TR Monitoring Provisions The TR subject units, 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. EQUI No.: EQUI 5 (Combustion Turbine #2)

Parameter 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 excepted 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 ----------------

EQUI No.: EQUI 6 (Duct Burner (Combustion Turbine #2))



systems (CEMS)






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



SO2

X ----------------

NOX

X -------------

Heat input

X ----------------

EQUI No.: EQUI 16 (Combustion Turbine #1)



systems (CEMS)






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



SO2

X ----------------

NOX

X -------------

Heat input

X ----------------

EQUI No.: EQUI 17 (Duct Burners (Combustion Turbine #1))



systems (CEMS)






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



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 (TR NOX Annual Trading Program) and 40 CFR 97.730 through 97.735 (TR SO2 Group 2 Trading Program). 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 (TR NOX Annual Trading Program) and 40 CFR 97.735 (TR SO2 Group 2 Trading

Program). 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 (TR NOX Annual Trading Program and 97.730 through 97.734 (TR SO2 Group 2 Trading Program) must submit to the Administrator a petition requesting approval of the alternative in accordance with 40 CFR 75.66 and 40 CFR 97.435 (TR NOX Annual Trading Program) and 40 CFR 97.735 (TR SO2 Group 2 Trading Program). 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 (TR NOX Annual Trading Program and 40 CFR 97.730 through 97.734 (TR SO2 Group 2 Trading Program), 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.

http://www.epa.gov/airmarkets/emissions/petitions.html

http://www.epa.gov/airmarkets/emissions/petitions.html

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