Air Individual Permit Part 70 Reissuance No. 07100002-014 ... · Permit issued: June 6, 2017 07100002-014 Permit expires: June 6, 2022 Page 32 of 281 Subject Item Sec. SI.Regt SI

Air Individual Permit

Part 70 Reissuance

07100002-014 Permittee: Boise White Paper LLC - Intl Falls

Facility name: Boise White Paper LLC - Intl Falls 400 2nd St International Falls, MN 56649-2327 Koochiching County

Expiration date: June 6, 2022 All Title I Conditions do not expire Stage 1 issuance date – Authorization to Construct and Operate: May 17, 2017 Stage 2 issuance date – Part 70 Reissuance: June 6, 2017 Permit characteristics: Federal; Part 70/ Major for NSR; Limits to avoid NSR The emission units, control equipment and emission stacks at the stationary source authorized in this permit reissuance are as described in the Permit Applications Table. The conditions included in Stage 1 of this permit action are effective on the Stage 1 Issuance Date shown above. Stage 1 conditions authorize construction and modification of the facility and the operation of the modified emissions units at the address listed above until final action is taken on Stage 2. Air Emission Permit No. 07100002- 013 remains effective until the Stage 2 Issue Date. Beginning on the Stage 2 Issue date Air Emission Permit No. 07100002-014 supersedes Air Emission Permit No. 07100002- 013 and authorizes the Permittee to modify 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 are enforceable by EPA Administrator or citizens under the Clean Air Act.

Stage 1 Issuance Approval:

Signature: Toni Volkmeier This document has been electronically signed. for the Minnesota Pollution Control Agency

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

Stage 2 Issuance Approval:

Signature: Toni Volkmeier This document has been electronically signed. for the Minnesota Pollution Control Agency

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

Permit issued: June 6, 2017 07100002-014 Permit expires: June 6, 2022 Page 3 of 281

Table of Contents

Page

1. Permit applications table .............................................................................................................................................. 4 2. Where to send submittals ............................................................................................................................................ 5 3. Facility description ........................................................................................................................................................ 6 4. Summary of subject items ............................................................................................................................................ 7 5. Limits and other requirements ...................................................................................................................................30 6. Submittal/action requirements ................................................................................................................................136 7. Appendices ...............................................................................................................................................................158

Appendix A. Insignificant Activities and General Applicable Requirements Appendix B. Ambient TRS Plan Appendix C. Equation to show compliance with 40 CFR Pt. 63, Subp. JJJJ Appendix D. Fugitive Emissions Control Plan Appendix E. Air Toxics Review - January, 1999 Appendix F. UNOX Alternative Monitoring Appendix G. Scrubber Pressure Drop Monitoring Parameters Appendix H. Alternative MACT PM Limits Appendix I. Modeling Parameters

Appendix J. 40 CFR pt. 63, subp. A General Provisions


1. Permit applications table Title description Application receipt date Action number Major Amendment 04/18/2016 07100002-014 Part 70 Reissuance 07/28/2014 07100002-014


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

Or Email a signed and scanned PDF copy to: [email protected] (for submittals related to stack testing) [email protected] (for other compliance submittals) (See complete email instructions in “Routine Air Report Instructions Letter” at http://www.pca.state.mn.us/nwqh472.)

mailto:[email protected]


http://www.pca.state.mn.us/nwqh472


3. Facility description

The Boise White Paper LLC - Intl Falls (Facility) is located at 400 2nd St in International Falls, MN, Koochiching County, Minnesota. Boise operates an integrated kraft pulp and paper mill. The paper mill manufactures a variety of coated and uncoated fine paper products. The Facility consists of a wood yard, chip processing center, pulp mill, bleach plant, chemical recovery system, power plant, wastewater treatment facility, industrial landfill, paper mill, finishing and sheeting, warehouse, and shipping facilities. A major permit amendment was incorporated into the permit to increase the total facility black liquor solids (BLS) production limit from 44,200 to 46,410 tons per month using a 12-month rolling average. As part of the Kraft pulping process, the facility produces black liquor. The black liquor is the material from the pulping process that contains much of the organic material that was originally in the wood and almost all of the inorganic material that was used in the digesting process. The solids in the black liquor are called black liquor solids (BLS). The black liquor is burned in the recovery furnace to recover the energy from the BLS and to recover the inorganic material for reuse.


4. Summary of subject items

SI ID: Description

Relationship Type

Related SI ID: Description

ACTV6: All IA's COMG11: ClO2 Generator

has members

EQUI57, EQUI60, EQUI61, EQUI62, EQUI63, EQUI82, EQUI936, EQUI937, EQUI953, EQUI963, EQUI964, EQUI965, STRU75, TREA12

COMG12: Bleach Plant has members

EQUI64, EQUI65, EQUI66, EQUI67, EQUI71, EQUI83, EQUI84, EQUI947, EQUI952, EQUI966, EQUI967, EQUI968, STRU75, TREA13

COMG13: 40 CFR pt. 63, subp. DDDDD Requirements

has members

EQUI15, EQUI16, EQUI17, EQUI18

COMG14: 40 CFR pt. 63, subp. S Requirements

has members

EQUI2, EQUI3, EQUI9, EQUI13, EQUI15, EQUI16, EQUI31, EQUI32, EQUI33, EQUI34, EQUI36, EQUI37, EQUI44, EQUI64, EQUI65, EQUI66, EQUI67,

SI ID: Description

Relationship Type

Related SI ID: Description EQUI71, EQUI938, EQUI939, EQUI950, EQUI951, EQUI952, EQUI956, EQUI957, EQUI958, EQUI959, EQUI961, EQUI966, EQUI967, EQUI968, EQUI972, EQUI973, EQUI974, EQUI975, EQUI976, EQUI977, EQUI978, EQUI979, TREA13, TREA16, TREA17, TREA18, TREA19

COMG15: 40 CFR pt. 63, subp. MM Requirements

has members

EQUI9, EQUI13, EQUI945, TREA1, TREA2, TREA3, TREA4, TREA15, TREA16, TREA17

COMG16: Internal Combustion Engines

has members

EQUI941, EQUI942, EQUI943

COMG19: Three Causticizers, Lime Slaker

has members

EQUI28, EQUI29, EQUI30, EQUI48

COMG5: NOx Cap Group Limits

has members

EQUI9, EQUI13, EQUI15, EQUI16, EQUI17, EQUI18, EQUI945

COMG6: LVHC NCG has EQUI2, EQUI13,


SI ID: Description

Relationship Type


Incineration and Venting members EQUI15, EQUI16, EQUI31, EQUI32, EQUI33, EQUI34, EQUI36, EQUI37, EQUI938, EQUI961, EQUI979, STRU78, STRU79, TREA16, TREA18, TREA19

COMG7: Kraft Pulping Process Condensates

has members

EQUI28, EQUI29, EQUI30, EQUI31, EQUI34, EQUI37, EQUI48, EQUI961, STRU108, STRU109, TREA38

COMG8: HVLC NCG Incineration and Venting

has members

EQUI3, EQUI9, EQUI939, EQUI950, EQUI951, EQUI956, EQUI957, EQUI958, EQUI959, EQUI972, EQUI973, EQUI974, EQUI975, EQUI976, EQUI977, EQUI978, STRU80, STRU81, STRU112, TREA17

EQUI108: Lime Kiln H2O Pressure - ParametricMonitor

sends to EQUI74: DAHS

EQUI109: Boiler 1 O2 monitors EQUI15: Boiler

SI ID: Description

Relationship Type


CEM - Continuous Emission Monitor

#1 - Boiler

EQUI109: Boiler 1 O2 CEM - Continuous Emission Monitor


EQUI110: Boiler 1 NOx CEM - Continuous Emission Monitor

monitors EQUI15: Boiler #1 - Boiler

EQUI110: Boiler 1 NOx CEM - Continuous Emission Monitor






EQUI116: SDT scrubber pressure drop


EQUI124: Recovery Furnace O2 CEM - Continuous Emission Monitor


EQUI124: Recovery Furnace O2 CEM - Continuous Emission Monitor

monitors EQUI9: Recovery Furnace -Furnace

EQUI125: Lime Kiln O2 CEM - Continuous Emission Monitor

monitors EQUI13: Lime Kiln - Kiln

EQUI125: Lime Kiln O2 CEM - Continuous Emission Monitor


EQUI126: Lime Kiln Liquid Flow Rate - Parametric Monitor


EQUI128: Boiler 3 NOX CEM - Continuous Emission Monitor




EQUI12: Paint Spray Booth - Spray Booth/Coating Line

sends to STRU74: Paint Booth Exhaust

EQUI12: Paint Spray Booth - Spray

is controlled by

TREA30: Paper Filter (Not


SI ID: Description

Relationship Type


Booth/Coating Line Accordian) - Spray Booth













EQUI13: Lime Kiln - Kiln sends to EQUI74: DAHS EQUI13: Lime Kiln - Kiln is monitored

by EQUI78: Lime Kiln TRS CEM - Continuous Emission Monitor

EQUI13: Lime Kiln - Kiln sends to STRU111: Lime Kiln

EQUI13: Lime Kiln - Kiln sends to STRU11: NGC Line Pressure Ejector Outlet Rupture Disk

EQUI13: Lime Kiln - Kiln sends to STRU12: Kiln-End Mill Rupture Disk

EQUI13: Lime Kiln - Kiln sends to STRU13: NGC Line Pressure Ejector Inlet Rupture Disk

EQUI13: Lime Kiln - Kiln sends to STRU143: Lime Kiln NCG Rupture Disk

EQUI13: Lime Kiln - Kiln sends to STRU37: NCG Lime Kiln Vent

EQUI13: Lime Kiln - Kiln is controlled by

TREA15: Venturi Scrubber - Lime

SI ID: Description

Relationship Type

Related SI ID: Description Kiln

EQUI13: Lime Kiln - Kiln includes TREA16: Other - Comb. of NCG Lime Kiln

EQUI13: Lime Kiln - Kiln is controlled by

TREA4: Centrifugal Collector - Lime Kiln

EQUI15: Boiler #1 - Boiler sends to EQUI74: DAHS EQUI15: Boiler #1 - Boiler sends to STRU144: NCG

Boiler Vent EQUI15: Boiler #1 - Boiler sends to STRU18: #1

Boiler Stack EQUI15: Boiler #1 - Boiler includes TREA18: Other

- Comb. of NCG Blr #1

EQUI16: Boiler #2 - Boiler sends to EQUI74: DAHS EQUI16: Boiler #2 - Boiler sends to STRU145: #2

Boiler Stack (Bypass Stack)

EQUI16: Boiler #2 - Boiler sends to STRU146: #2 Boiler Stack

EQUI16: Boiler #2 - Boiler is controlled by

TREA10: Centrifugal Collector - Boiler 2

EQUI16: Boiler #2 - Boiler includes TREA19: Other - Comb. of NCG Blr #2

EQUI16: Boiler #2 - Boiler is controlled by

TREA5: Electrostatic Precipitator - Boiler 2


Boiler Stack EQUI17: Boiler #3 - Boiler is controlled

by TREA20: Flue Gas Recirculation


Boiler Stack EQUI18: Boiler #9 - Boiler is controlled

by TREA22: Flue Gas Recirculation

EQUI19: No. 2 Paper sends to STRU148: #2


SI ID: Description

Relationship Type


Machine - Other Emission Unit

P.M. - #2 Exhaust Vent

EQUI19: No. 2 Paper Machine - Other Emission Unit

sends to STRU149: #2 P.M. - #3 Exhaust Vent






sends to STRU33: Vacuum Vent off #2 PM


sends to STRU34: Dryer Vent off #2 PM










sends to STRU88: Vacuum Pumps (No. 3 & 4 PM) (BM)


sends to STRU89: North Exhaust Vent Between #3 & 4 PM's


sends to STRU38: #4 PM Gas-Fired Dryer Exhaust


sends to STRU88: Vacuum Pumps (No. 3 & 4 PM) (BM)


sends to STRU89: North Exhaust Vent Between #3 &

SI ID: Description

Relationship Type

Related SI ID: Description 4 PM's


sends to STRU90: Exhaust Vent North of #4 penthouse










sends to STRU95: No. 4 PM Coater Dryer Exhaust


sends to STRU100: #1 Wet End False Ceiling Exhaust Vent




sends to STRU103: Deaerator Vacuum Relief Vent






sends to STRU44: Saveall Exhaust Vent


sends to STRU45: Roof Exhaust Vent #1

EQUI22: No. 1 Paper sends to STRU46: Roof


SI ID: Description

Relationship Type



Exhaust Vent #2


sends to STRU47: Mainhood Exhaust Vent #1








sends to STRU51: False Ceiling Exhaust Vent


sends to STRU52: Afterhood Exhaust #5


sends to STRU53: Afterhood Exhaust #6


sends to STRU54: False Ceiling Exhaust Vent


sends to STRU55: Winder Pulper Exhaust Vent


sends to STRU96: Vacuum Pumps (10) (#1PM)


sends to STRU97: Size Press Pulper Exhaust Vent (#1PM)




sends to STRU99: #1 Wet End False Ceiling Exhaust

SI ID: Description

Relationship Type

Related SI ID: Description Vent

EQUI24: Sludge Dryer - Other Emission Unit

sends to STRU145: #2 Boiler Stack (Bypass Stack)


sends to STRU146: #2 Boiler Stack




sends to STRU76: Sludge Dryer


is controlled by

TREA18: Other - Comb. of NCG Blr #1


is controlled by



is controlled by

TREA24: Other - Sludge Dryer


is controlled by

TREA25: Venturi Scrubber - Sludge Dryer


is controlled by

TREA26: Spray Tower - Sludge Dryer

EQUI25: Off-Machine Coater - Other Emission Unit

sends to STRU107: EU 909 OMC Exhaust Vent

EQUI28: Causticizer #1 - Causticizing Equipment


EQUI2: Blow Heat Accumulator - Other Emission Unit

sends to STRU123: Blow Heat Accumulator Vent

EQUI2: Blow Heat Accumulator - Other Emission Unit

sends to STRU124: Blow Heat Accumulator Vent


EQUI31: Turpentine Decanter - Decanting Equipment

sends to STRU111: Lime Kiln

EQUI31: Turpentine sends to STRU113:


SI ID: Description

Relationship Type


Decanter - Decanting Equipment

Turpentine Decanter Rupture Disk


sends to STRU114: Turpentine Decanters Emergency Vent


sends to STRU11: NGC Line Pressure Ejector Outlet Rupture Disk


sends to STRU12: Kiln-End Mill Rupture Disk


sends to STRU13: NGC Line Pressure Ejector Inlet Rupture Disk


sends to STRU143: Lime Kiln NCG Rupture Disk


sends to STRU144: NCG Boiler Vent








sends to STRU37: NCG Lime Kiln Vent


sends to STRU7: NCG Header Rupture Disk


is controlled by



is controlled by

TREA15: Venturi Scrubber - Lime

SI ID: Description

Relationship Type

Related SI ID: Description Kiln


is controlled by

TREA16: Other - Comb. of NCG Lime Kiln


is controlled by



is controlled by



is controlled by



is controlled by


EQUI32: Turpentine Relief Condenser dig. 1-4 - Other Emission Unit



















SI ID: Description

Relationship Type





sends to STRU5: Turpentine Condenser 1-4 Rupture Disk


sends to STRU6: Turpentine Condenser 1-4 Emergency Vent




is controlled by



is controlled by

TREA15: Venturi Scrubber - Lime Kiln


is controlled by



is controlled by



is controlled by



is controlled by



is controlled by





sends to STRU115: Turpentine Condenser 5-8 Rupture Disk

SI ID: Description

Relationship Type



sends to STRU116: Turpentine Condenser 5-8 Emergency Vent






















is controlled by



is controlled by


EQUI33: Turpentine Relief Condenser dig. 5-8

is controlled by

TREA16: Other - Comb. of NCG


SI ID: Description

Relationship Type


- Other Emission Unit Lime Kiln EQUI33: Turpentine Relief Condenser dig. 5-8 - Other Emission Unit

is controlled by



is controlled by



is controlled by



is controlled by


EQUI34: Pre-evaporator Hotwell - Other Emission Unit



sends to STRU117: Pre-evaporator Hotwell Rupture Disk


sends to STRU118: Pre-evaporator Hotwell Emergency Vent













SI ID: Description

Relationship Type











is controlled by



is controlled by



is controlled by



is controlled by



is controlled by



is controlled by



is controlled by


EQUI36: Blow Heat Secondary Condenser - Other Emission Unit





sends to STRU121: Blow Heat Secondary Condenser


SI ID: Description

Relationship Type

Related SI ID: Description Rupture Disk


sends to STRU122: Blow Heat Secondary Condenser Emergency Vent




















is controlled by



is controlled by



is controlled by


EQUI36: Blow Heat Secondary Condenser -

is controlled by

TREA18: Other - Comb. of NCG

SI ID: Description

Relationship Type


Other Emission Unit Blr #1 EQUI36: Blow Heat Secondary Condenser - Other Emission Unit

is controlled by



is controlled by



is controlled by


EQUI37: Evaporator Hotwell - Other Emission Unit







sends to STRU138: Evaporator Hotwell Rupture Disk


sends to STRU139: Evaporator Hotwell Emergency Vent




sends to STRU140: Evaporator NCG Line Rupture Disk





EQUI37: Evaporator Hotwell - Other Emission



SI ID: Description

Relationship Type


Unit (Bypass Stack) EQUI37: Evaporator Hotwell - Other Emission Unit







is controlled by



is controlled by



is controlled by



is controlled by



is controlled by



is controlled by



is controlled by


EQUI3: Brown Stock Washing - Washer

sends to STRU110: Smelt Dissolving Tank


sends to STRU150: Recovery Furnace


sends to STRU20: Brown Stock Decker


is controlled by

TREA17: Other - Comb. of NCG Rec. Furn

EQUI3: Brown Stock is controlled TREA1:

SI ID: Description

Relationship Type


Washing - Washer by Electrostatic Precipitator - Recovery Furnace


is controlled by

TREA2: Venturi Scrubber - Smelt Dissolving Tank


is controlled by


EQUI44: Brown Stock Decker - Other Emission Unit


EQUI48: Lime Slaker - Other Emission Unit

EQUI49: Reburned Lime Bin - Other Emission Unit

sends to STRU85: Reburned LIme Bin/ Fabric Filter

EQUI49: Reburned Lime Bin - Other Emission Unit

is controlled by

TREA35: Fabric Filter - Reburned Lime Bin

EQUI52: UNOX A Basin - Other Emission Unit

sends to STRU108: UNOX A Basin

EQUI52: UNOX A Basin - Other Emission Unit

is controlled by

TREA32: Other - UNOX Basins

EQUI53: UNOX B Basin - Other Emission Unit

sends to STRU109: UNOX B Basin

EQUI53: UNOX B Basin - Other Emission Unit

is controlled by


EQUI57: Sewer Vent (L8) - Bleaching Equipment

sends to STRU75: Combined SV220 and SV240 (ClO2 Generator & Bleach Plant)

EQUI57: Sewer Vent (L8) - Bleaching Equipment

is controlled by

TREA12: Wet Scrubber - Cl02 Generator

EQUI60: Barametric Condenser - Bleaching Equipment

sends to STRU75: Combined SV220 and SV240 (ClO2 Generator &


SI ID: Description

Relationship Type

Related SI ID: Description Bleach Plant)

EQUI60: Barametric Condenser - Bleaching Equipment

is controlled by


EQUI61: Saltcake Filter - Bleaching Equipment


EQUI61: Saltcake Filter - Bleaching Equipment

is controlled by


EQUI62: Saltcake Hydroclone - Bleaching Equipment


EQUI62: Saltcake Hydroclone - Bleaching Equipment

is controlled by


EQUI63: Anti-Siphon Vent - Bleaching Equipment


EQUI63: Anti-Siphon Vent - Bleaching Equipment

is controlled by


EQUI64: D/C Tower - Bleaching Equipment


EQUI64: D/C Tower - Bleaching Equipment

is controlled by

TREA13: Wet Scrubber - Bleach Plant

EQUI65: D Tower - Bleaching Equipment


EQUI65: D Tower - Bleaching Equipment

is controlled by

TREA13: Wet Scrubber -

SI ID: Description

Relationship Type

Related SI ID: Description Bleach Plant

EQUI66: D/C Blend Chest - Bleaching Equipment


EQUI66: D/C Blend Chest - Bleaching Equipment

is controlled by


EQUI67: D-Mixer Sample Pot. - Bleaching Equipment


EQUI67: D-Mixer Sample Pot. - Bleaching Equipment

is controlled by


EQUI71: Acid Sewer Vent - Bleaching Equipment


EQUI71: Acid Sewer Vent - Bleaching Equipment

is controlled by


EQUI74: DAHS EQUI75: Orion CyberGreen CEM DAS (DAHS backup)

EQUI76: Data Historian EQUI77: Disributive Control System (DCS)

EQUI78: Lime Kiln TRS CEM - Continuous Emission Monitor


EQUI79: Recovery Furnace Opacity COM - Continuous Opacity Monitor


EQUI79: Recovery Furnace Opacity COM - Continuous Opacity Monitor


EQUI80: Boiler 2 Opacity monitors EQUI16: Boiler


SI ID: Description

Relationship Type


COM - Continuous Opacity Monitor

#2 - Boiler

EQUI80: Boiler 2 Opacity COM - Continuous Opacity Monitor


EQUI81: SDT scrubber flow - Parametric Monitor


EQUI82: ClO2 scrubber liquid supply flow rate - Parametric Monitor


EQUI83: Bleach Plant scrubber liquid supply flow rate - Parametric Monitor


EQUI84: Bleach Plant scrubber pH - Parametric Monitor


EQUI86: Recovery Furnace NOx CEM - Continuous Emission Monitor


EQUI86: Recovery Furnace NOx CEM - Continuous Emission Monitor


EQUI87: Recovery Furnace TRS CEM - Continuous Emission Monitor


EQUI87: Recovery Furnace TRS CEM - Continuous Emission Monitor


EQUI88: Recovery Furnace CO CEM - Continuous Emission Monitor


EQUI88: Recovery Furnace CO CEM - Continuous Emission Monitor


EQUI90: Boiler 2 CO CEM - Continuous Emission Monitor


EQUI90: Boiler 2 CO CEM - Continuous Emission


SI ID: Description

Relationship Type


Monitor EQUI936: CLO2 Tower Seal Tank - Bleaching Equipment


EQUI936: CLO2 Tower Seal Tank - Bleaching Equipment

is controlled by


EQUI937: ClO2 Generator - Bleaching Equipment


EQUI937: ClO2 Generator - Bleaching Equipment

is controlled by


EQUI938: Turpentine Water Pad Tank



















sends to STRU7: NCG Header


SI ID: Description

Relationship Type

Related SI ID: Description Rupture Disk


is controlled by



is controlled by



is controlled by


EQUI939: Sluice Bowl sends to STRU112: HVLC Recovery Vent

EQUI939: Sluice Bowl sends to STRU150: Recovery Furnace

EQUI939: Sluice Bowl is controlled by


EQUI939: Sluice Bowl is controlled by

TREA1: Electrostatic Precipitator - Recovery Furnace

EQUI940: Intermediate Chip Cyclone

sends to STRU82: Intermediate Chip Cyclone

EQUI941: Lime Kiln Auxilliary Engine

EQUI942: Fire Pump #3 Engine

EQUI943: Guard Standby Generator

EQUI944: Wastewater Treatment Plant Cooling Tower

sends to STRU72: Cooling Tower

EQUI945: Smelt Dissolving Tank



is controlled by



is controlled by

TREA3: Venturi Scrubber - Smelt

SI ID: Description

Relationship Type

Related SI ID: Description Dissolving Tank

EQUI947: Bleach Plant scrubber fan - Parametric Monitor


EQUI948: Boiler 2 Airflow Meter


EQUI948: Boiler 2 Airflow Meter


EQUI949: Boiler 2 NOX & SO2 CEM


EQUI949: Boiler 2 NOX & SO2 CEM


EQUI950: Hopper Flush Tank

sends to STRU112: HVLC Recovery Vent




is controlled by



is controlled by


EQUI951: Rapid Drain Tank





sends to STRU17: Rapid Drain Tank Vent


is controlled by



is controlled by


EQUI952: EO Filt. Tank sends to STRU75: Combined SV220 and SV240 (ClO2 Generator & Bleach Plant)


SI ID: Description

Relationship Type


EQUI952: EO Filt. Tank is controlled by


EQUI953: Saltcake Mix Tank


EQUI953: Saltcake Mix Tank

is controlled by


EQUI954: Green Liquor Storage Tank

sends to STRU142: Green Liquor Storage Tank Vent

EQUI955: Green Liquor Clarifier

sends to STRU141: Green Liquor Clarifier Tank Vent

EQUI956: Precipitator Saltcake Mix Tank





is controlled by



is controlled by


EQUI957: 55% BLS Tank sends to STRU110: Smelt Dissolving Tank

EQUI957: 55% BLS Tank sends to STRU112: HVLC Recovery Vent

EQUI957: 55% BLS Tank sends to STRU136: 55% Black Liquor Tank Rupture Disk

EQUI957: 55% BLS Tank sends to STRU137: 55% Black Liquor Tank Emergency Vent

SI ID: Description

Relationship Type


EQUI957: 55% BLS Tank sends to STRU150: Recovery Furnace

EQUI957: 55% BLS Tank is controlled by








EQUI958: HL Swing Tank sends to STRU112: HVLC Recovery Vent

EQUI958: HL Swing Tank sends to STRU134: Heavy Liquor Swing Tank Rupture Disk

EQUI958: HL Swing Tank sends to STRU135: Heavy Liquor Swing Tank Emergency Vent

EQUI958: HL Swing Tank sends to STRU150: Recovery Furnace

EQUI958: HL Swing Tank is controlled by


EQUI958: HL Swing Tank is controlled by


EQUI959: 72% BLS Tank sends to STRU10: 72% Black Liquor Tank Emergency Vent

EQUI959: 72% BLS Tank sends to STRU110:


SI ID: Description

Relationship Type

Related SI ID: Description Smelt Dissolving Tank



EQUI959: 72% BLS Tank sends to STRU9: 72% Black Liquor Tank Rupture Disk









EQUI960: 18% Liquor Tank

sends to STRU132: 18% Liquor Tank Vent

EQUI960: 18% Liquor Tank

sends to STRU133: 18% Liquor Tank Vent

EQUI961: Stripper Feed Tank



sends to STRU119: Stripper Feed Tank Rupture Disk




sends to STRU120: Stripper Feed Tank Emergency

SI ID: Description

Relationship Type

Related SI ID: Description Vent




















is controlled by



is controlled by



is controlled by



is controlled by



is controlled by



is controlled by


EQUI961: Stripper Feed is controlled TREA5:


SI ID: Description

Relationship Type


Tank by Electrostatic Precipitator - Boiler 2

EQUI962: 14% Black Liquor Tank

sends to STRU127: 14% Black Liquor Tank Vent

EQUI963: ClO2 Storage Tank B


EQUI963: ClO2 Storage Tank B

is controlled by


EQUI964: Dump Tank sends to STRU75: Combined SV220 and SV240 (ClO2 Generator & Bleach Plant)

EQUI964: Dump Tank is controlled by


EQUI965: ClO2 Storage Tank A


EQUI965: ClO2 Storage Tank A

is controlled by


EQUI966: Chlorine Blowdown Tank


EQUI966: Chlorine Blowdown Tank

is controlled by


EQUI967: D Filt. Tank sends to STRU75: Combined SV220 and SV240 (ClO2 Generator & Bleach Plant)

SI ID: Description

Relationship Type


EQUI967: D Filt. Tank is controlled by


EQUI968: D/C Filt. Tank sends to STRU75: Combined SV220 and SV240 (ClO2 Generator & Bleach Plant)

EQUI968: D/C Filt. Tank is controlled by


EQUI969: #9 & #10 Brown Stock High Density Storage Tank

sends to STRU128: #9 Brown Stock HD Towers Vent







EQUI971: Dirty Hot Water Tank

sends to STRU126: Dirty Hot Water Tank Vent

EQUI972: #3 Filtrate Tank sends to STRU150: Recovery Furnace

EQUI972: #3 Filtrate Tank sends to STRU75: Combined SV220 and SV240 (ClO2 Generator & Bleach Plant)

EQUI972: #3 Filtrate Tank is controlled by





SI ID: Description

Relationship Type


EQUI973: #2 Filtrate Tank sends to STRU150: Recovery Furnace

EQUI973: #2 Filtrate Tank sends to STRU75: Combined SV220 and SV240 (ClO2 Generator & Bleach Plant)





EQUI974: Foam System sends to STRU110: Smelt Dissolving Tank

EQUI974: Foam System sends to STRU125: Foam System (Foam Chest)

EQUI974: Foam System sends to STRU150: Recovery Furnace

EQUI974: Foam System is controlled by








EQUI975: Knot Tank sends to STRU112: HVLC Recovery Vent

EQUI975: Knot Tank sends to STRU150: Recovery Furnace

SI ID: Description

Relationship Type


EQUI975: Knot Tank is controlled by


EQUI975: Knot Tank is controlled by


EQUI976: #1 Filtrate Tank Foam Breaker







is controlled by



is controlled by



is controlled by



is controlled by


EQUI977: Blow Tank sends to STRU112: HVLC Recovery Vent

EQUI977: Blow Tank sends to STRU150: Recovery Furnace

EQUI977: Blow Tank is controlled by


EQUI977: Blow Tank is controlled by


EQUI978: 62% BLS Tank sends to STRU110: Smelt


SI ID: Description

Relationship Type

Related SI ID: Description Dissolving Tank



EQUI978: 62% BLS Tank sends to STRU80: 62% BL Storage Tank Emergency Vent

EQUI978: 62% BLS Tank sends to STRU81: 62% BL Storage Tank Rupture Disk









EQUI979: Turpentine Storage Tank










SI ID: Description

Relationship Type













is controlled by



is controlled by



is controlled by


EQUI9: Recovery Furnace -Furnace





includes TREA17: Other - Comb. of NCG Rec. Furn


is controlled by


FUGI3: Wastewater Treatment Plant Primary Clarifier. - Process Emissions

FUGI4: Roundwood Trucks & Log Loader Paved Roads - Paved Road

FUGI5: Roundwood Trucks and Log Loader


SI ID: Description

Relationship Type


Unpaved Roads - Unpaved Roads STRU100: #1 Wet End False Ceiling Exhaust Vent

STRU101: #1 Wet End False Ceiling Exhaust Vent

STRU102: Vacuum Line Relief Vent

STRU103: Deaerator Vacuum Relief Vent

STRU104: Wet End Transformer Exhaust Vent

STRU105: Wet End Transformer Exhaust Vent

STRU106: Unused roof drain or process drain

STRU107: EU 909 OMC Exhaust Vent

STRU108: UNOX A Basin STRU109: UNOX B Basin STRU10: 72% Black Liquor Tank Emergency Vent

STRU110: Smelt Dissolving Tank

STRU111: Lime Kiln STRU112: HVLC Recovery Vent

STRU113: Turpentine Decanter Rupture Disk

STRU114: Turpentine Decanters Emergency Vent

STRU115: Turpentine Condenser 5-8 Rupture Disk

STRU116: Turpentine Condenser 5-8 Emergency Vent

STRU117: Pre-evaporator Hotwell Rupture Disk

STRU118: Pre-evaporator

SI ID: Description

Relationship Type


Hotwell Emergency Vent STRU119: Stripper Feed Tank Rupture Disk

STRU11: NGC Line Pressure Ejector Outlet Rupture Disk

STRU120: Stripper Feed Tank Emergency Vent

STRU121: Blow Heat Secondary Condenser Rupture Disk

STRU122: Blow Heat Secondary Condenser Emergency Vent

STRU123: Blow Heat Accumulator Vent

STRU124: Blow Heat Accumulator Vent

STRU125: Foam System (Foam Chest)

STRU126: Dirty Hot Water Tank Vent

STRU127: 14% Black Liquor Tank Vent

STRU128: #9 Brown Stock HD Towers Vent


STRU12: Kiln-End Mill Rupture Disk



STRU132: 18% Liquor Tank Vent

STRU133: 18% Liquor Tank Vent

STRU134: Heavy Liquor Swing Tank Rupture Disk

STRU135: Heavy Liquor Swing Tank Emergency Vent

STRU136: 55% Black Liquor Tank Rupture Disk


SI ID: Description

Relationship Type


STRU137: 55% Black Liquor Tank Emergency Vent

STRU138: Evaporator Hotwell Rupture Disk

STRU139: Evaporator Hotwell Emergency Vent

STRU13: NGC Line Pressure Ejector Inlet Rupture Disk

STRU140: Evaporator NCG Line Rupture Disk

STRU141: Green Liquor Clarifier Tank Vent

STRU142: Green Liquor Storage Tank Vent

STRU143: Lime Kiln NCG Rupture Disk

STRU144: NCG Boiler Vent

STRU145: #2 Boiler Stack (Bypass Stack)

STRU146: #2 Boiler Stack STRU147: #3 Boiler Stack STRU148: #2 P.M. - #2 Exhaust Vent

STRU149: #2 P.M. - #3 Exhaust Vent

STRU150: Recovery Furnace

STRU17: Rapid Drain Tank Vent

STRU18: #1 Boiler Stack STRU20: Brown Stock Decker

STRU30: #9 Boiler Stack STRU31: #2 P.M. - #1 Exhaust Vent


STRU33: Vacuum Vent off #2 PM

STRU34: Dryer Vent off #2 PM

STRU35: #3 P.M. - #3

SI ID: Description

Relationship Type


Exhaust Vent STRU36: #3 P.M. - #4 Exhaust Vent

STRU37: NCG Lime Kiln Vent

STRU38: #4 PM Gas-Fired Dryer Exhaust



STRU44: Saveall Exhaust Vent

STRU45: Roof Exhaust Vent #1

STRU46: Roof Exhaust Vent #2

STRU47: Mainhood Exhaust Vent #1




STRU51: False Ceiling Exhaust Vent

STRU52: Afterhood Exhaust #5

STRU53: Afterhood Exhaust #6

STRU54: False Ceiling Exhaust Vent

STRU55: Winder Pulper Exhaust Vent

STRU5: Turpentine Condenser 1-4 Rupture Disk

STRU6: Turpentine Condenser 1-4 Emergency Vent

STRU71: Refined Room Roof Vent


SI ID: Description

Relationship Type


STRU72: Cooling Tower STRU74: Paint Booth Exhaust

STRU75: Combined SV220 and SV240 (ClO2 Generator & Bleach Plant)

STRU76: Sludge Dryer STRU78: Turpentine Pad Water and Storage Tanks Rupture Disks

STRU79: Blow Heat Rupture Disk

STRU7: NCG Header Rupture Disk

STRU80: 62% BL Storage Tank Emergency Vent

STRU81: 62% BL Storage Tank Rupture Disk

STRU82: Intermediate Chip Cyclone

STRU85: Reburned LIme Bin/ Fabric Filter



STRU88: Vacuum Pumps (No. 3 & 4 PM) (BM)

STRU89: North Exhaust Vent Between #3 & 4 PM's

STRU90: Exhaust Vent North of #4 penthouse





STRU95: No. 4 PM Coater Dryer Exhaust

STRU96: Vacuum Pumps

SI ID: Description

Relationship Type


(10) (#1PM) STRU97: Size Press Pulper Exhaust Vent (#1PM)



STRU9: 72% Black Liquor Tank Rupture Disk

TFAC5: Boise White Paper LLC - Intl Falls


is controlled in series by





is monitored by

EQUI82: ClO2 scrubber liquid supply flow rate - Parametric Monitor




is monitored by

EQUI83: Bleach Plant scrubber liquid supply flow rate - Parametric Monitor


is monitored by

EQUI84: Bleach Plant scrubber pH - Parametric Monitor


is monitored by

EQUI947: Bleach Plant scrubber fan - Parametric Monitor


is monitored by

EQUI108: Lime Kiln H2O Pressure - ParametricMonitor


SI ID: Description

Relationship Type



is monitored by

EQUI126: Lime Kiln Liquid Flow Rate - Parametric Monitor













is controlled in parallel by



is controlled in parallel by










TREA20: Flue Gas Recirculation

TREA22: Flue Gas Recirculation



TREA25: Venturi

SI ID: Description

Relationship Type

Related SI ID: Description Scrubber - Sludge Dryer




TREA25: Venturi Scrubber - Sludge Dryer


TREA27: Centrifugal Collector - High Efficiency




is monitored by





is monitored by

EQUI81: SDT scrubber flow - Parametric Monitor

TREA30: Paper Filter (Not Accordian) - Spray Booth



TREA34: Fabric Filter - Low Temperature, i.e., T<180 Degrees F

TREA35: Fabric Filter - Reburned Lime Bin

TREA36: Other TREA37: Other TREA38: Other TREA3: Venturi Scrubber - Smelt Dissolving Tank

is monitored by





is monitored by

EQUI81: SDT scrubber flow - Parametric


SI ID: Description

Relationship Type

Related SI ID: Description Monitor











5. Limits and other requirements

Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation TFAC 5 07100002 Boise White

Paper LLC - Intl Falls

5.1.1 PERMIT SHIELD: Subject to the limitations in Minn. R. 7007.1800, compliance with the conditions of this permit shall be deemed compliance with the specific provision of the applicable requirement identified in the permit as the basis of each condition.Subject to the limitations of Minn. R. 7007.1800 and 7017.0100, subp. 2, notwithstanding the conditions of this permit specifying compliance practices for applicable requirements, any person (including the Permittee) may also use other credible evidence to establish compliance or noncompliance with applicable requirements. This permit shall not alter or affect the liability of the Permittee for any violation of applicable requirements prior to or at the time of permit issuance. [Minn. R. 7007.1800, (A)(2)]

5.1.2 Permit Appendices: This permit contains appendices as listed in the permit Table of Contents. The Permittee shall comply with all requirements contained in Appendices A-J (Insignificant Activities, Ambient TRS Plan, 40 CFR Pt. 63, Subp. JJJJ compliance equation, Fugitive Emissions Control Plan, Air Toxics Report, UNOX Alternative Monitoring, Scrubber Pressure Drop Monitoring Parameters, Alternative MACT PM Limits, Modeling parameters, and 40 CFR pt. 63, subp. A requirements, respectively). Modeling parameters in Appendix I are included for reference only as described elsewhere in this permit. [Minn. R. 7007.0800, subp. 2]

5.1.3 The Permitte shall limit Black Liquor Solids (virgin bone dried basis) Production <= 46410 tons per month 12-month rolling average. [Title I Condition: 40 CFR 52.21(k)(Modeling) & Minn. R. 7007.3000]

5.1.4 Recordkeeping: Monthly record and monthly calculation of 12-month rolling average of the black liquor solids production, by the 15th of the following month. [Minn. R. 7007.0800, subp. 5, Title I Condition: 40 CFR 52.21(k)(Modeling) & Minn. R. 7007.3000]

5.1.5 Fugitive Emissions Control Plan: The Permittee has submitted a fugitive emissions control plan for review and approval by the Commissioner. The Plan is considered an enforceable part of the permit. The plan shall identify all fugitive emission sources, including


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation paved and unpaved roads, primary and contingent control measures, and recordkeeping. The Permitee shall follow the actions and recordkeeping specified in the control plan. The plan may be amended by the Permittee with the Commissioner's approval. If the Commissioner determines the Permitee is out of compliance with Minn. R. 7011.0150 or the fugitive emission control plan, then the Permittee may be required to amend the control plan and/or to install and operate particulate matter ambient monitors. [Minn. R. 7007.0800, subp. 2, Minn. Stat. 116.07, subd. 4a]

5.1.6 Ambient TRS Plan: The Ambient TRS Plan shall describe the steps to be taken to ensure that the ambient air TRS target is not exceeded. The Ambient TRS Plan has been submitted and approved by the MPCA on 10/2/2000 (permit -003 issuance date). This plan is an enforceable part of the permit and is listed in Appendix B. This is a state only requirement and is not federally enforceable or enforceable by citizens under the Act. [Minn. R. 7007.0800, subp. 2]

5.1.7 The Permittee shall continue to comply with the Ambient TRS Plan, except for those provisions related to operation and maintenance of the TRS monitor, after the monitor has been shut off (occurred on April 6, 2015). [Minn. R. 7007.0800, subp. 2]

5.1.8 The Permittee shall store any fuels falling under the definition of solid waste in accordance with Minn. R. 7035.2855. [Minn. R. 7035.2855]

5.1.9 Prior to operation of a storage facility, owners and operators shall obtain a written certification from an engineer licensed in Minnesota stating that the storage facility is designed and constructed to meet the requirements of this part. A copy of this certification shall be maintained on file by the owner or operator and shall be made available to the Agency upon request. [Minn. R. 7035.2855, subp. 7(A)]

5.1.10 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 40 CFR 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 40 CFR Section 52.21(r)(6)(vi)(b).


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

5.1.11 Preconstruction Documentation -- Before beginning actual construction on a project, the Permittee shall document the following: 1. Project description 2. Identification of any subject item (SI) whose emissions of an NSR pollutant could be affected 3. Pre-change potential emissions of any affected existing SI, and the projected post-change potential emissions of any affected existing or new SI. 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 SI 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]

5.1.12 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]


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation 5.1.13 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]

5.1.14 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]

5.1.15 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]

5.1.16 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]

5.1.17 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


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation 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. 7007.800, subp. 16(J)]

5.1.18 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]

5.1.19 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]

5.1.20 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]

5.1.21 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)]

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

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

5.1.24 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 The Notification, Test Plan, and Test Report must be submitted in a format specified by the commissioner. [Minn. R. 7017.2018, Minn. R. 7017.2030, subps. 1-4,


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation Minn. R. 7017.2035, subps. 1-2]

5.1.25 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]

5.1.26 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)]

5.1.27 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)]

5.1.28 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)]

5.1.29 Recordkeeping: Maintain records describing any insignificant modifications (as required by Minn. R. 7007.1250, subp. 3) or changes contravening permit


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

5.1.30 If the Permittee determines that no permit amendment or notification is required prior to making a change, the Permittee must retain records of all calculations required under Minn. R. 7007.1200. These records shall be kept for a period of five years from the date the change was made or until permit reissuance, whichever is longer. The records shall be kept at the stationary source for the current calendar year of operation and may be kept at the 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]

5.1.31 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]

5.1.32 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]

5.1.33 Notification of Deviations Endangering Human Health or the Environment: As soon as possible after discovery, notify the Commissioner or the state duty officer, either


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation orally or by facsimile, of any deviation from permit conditions which could endanger human health or the environment. [Minn. R. 7019.1000, subp. 1]

5.1.34 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]

5.1.35 Parameters Used in Modeling (non-criteria pollutants): If the Permittee proposes to emit any pollutant in addition to those listed in the Boise Cascade Air Toxics Review, dated January 1999 (summarized in Appendix E), or proposes to increase the emission rate of any pollutant, the Permittee shall first use the Air Toxics Review (ATR) as a template for re-evaluating the risk due to the change in emissions. If the proposed change may adversely affect the calculated risk, e.g. the change is an increase in one of the pollutants determined to be a risk driver, (i.e. a pollutant contributing to 95% of the acute, subchronic, or chronic hazard index or 95% of the excess cancer risk), then the Permittee shall submit a report to the MPCA of the proposed change and demonstrate that the recalculated risk for all pollutants emitted from the facility does not exceed the acceptable risk criteria used in the ATR. The Permittee shall receive written approval from the MPCA before making any changes. For changes that do not involve an increase in an emission rate or that do not seem likely to increase the calculated risk, the Permittee shall keep records of such changes. This report shall be submitted with the annual certification which describes these changes. This report shall include an explanation of why it was determined that notification to the MPCA was not necessary. For changes involving increases in emission rates and that require a minor permit amendment, the proposal shall be submitted as soon as practicable, but no less than 60 days before making the change to any parameter.


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation For changes involving increases in emission rates and that require a permit amendment other than a minor amendment, the proposal shall be submitted prior to or with the permit amendment application. [Minn. R. 7007.0800, subp. 2]

5.1.36 Modeled Parameters for NOx and SO2: The parameters used in NOx modeling for permit number 07100002-001 and SO2 modeling for permit number 07100002-011 are listed in Appendix I of this permit. The parameters describe the operation of the facility at maximum permitted capacity. The purpose of listing the parameters in the appendix is to provide a benchmark for future changes. [Minn. R. 7007.0100, subp. 7(A), 7(L), & 7(M), Minn. R. 7007.0800, subp. 4, Minn. R. 7007.0800, subps. 1-2, Minn. R. 7009.0010-7009.0080, Minn. Stat. 116.07, subd. 4a, Minn. Stat. 116.07, subd. 9, Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

5.1.37 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]

5.1.38 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 40 CFR 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)]

5.1.39 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]

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

COMG 5 GP420 NOx Cap Group


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation Limits

5.2.1 The Permittee shall limit emission of Nitrogen Oxides <= 3.67 tons per day from combustion sources (EQUI 9, EQUI 15, EQUI 16, EQUI 17, and EQUI 18). [Title I Condition: 40 CFR 52.21(o)(visibility) & Minn. R. 7007.3000]

5.2.2 Calculate: Calculate and record NOx emissions daily from combustion sources. The NOx emissions from EQUI 9, EQUI 15, EQUI 16, EQUI 17, and EQUI 18 shall be summed together and compared to the NOx limit for the combustion sources (3.67 tons/day). The NOx emissions from each subject item are to be determined from the NOx CEMS for that subject item. Any exceedances shall be reported on a semi-annual basis with the CEMS EERs. (Calculations associated with Title I Condition). [Title I Condition: 40 CFR 52.21(o)(visibility) & Minn. R. 7007.3000]

5.2.3 The Permittee shall limit emissions of Nitrogen Oxides <= 4.18 tons per day. This limit is the total NOx cap for the combustion sources (Boilers #1, #2, #3, #9, and the recovery furnace) (EQUI 15, EQUI 16, EQUI 17, EQUI 18, EQUI 9, respectively) as well as the lime kiln and smelt dissolving tank (EQUI 13 and EQUI 945). [Title I Condition: 40 CFR 52.21(o)(visibility) & Minn. R. 7007.3000]

5.2.4 Calculate: Calculate and record NOx emissions daily from the smelt dissolving tank (EQUI 945) and the lime kiln (EQUI 13). The NOx emissions shall be calculated by multiplying the emission factor determined from the most recent MPCA approved performance test and the applicable production rate. These NOx emissions shall be added to the emissions determined from the NOx CEMS on a daily basis and shall then be compared to the total NOx emission limit for COMG 5. Any exceedances shall be reported on a semi-annual basis with the CEMS EERs. (Calculations associated with Title I Condition). [Title I Condition: 40 CFR 52.21(o)(visibility) & Minn. R. 7007.3000]

5.2.5 Nitrogen Oxides: Protocol for Re-Setting the Emission Factor Used For Calculating Emissions: The Permittee shall conduct performance testing under conditions that produce the maximum emission rate, using US EPA reference method 7E to measure the emission factor as required elsewhere in this permit. The Permittee shall report the test result in lbs/hr for EQUI 13 and lbs/ton of BLS for EQUI 945 in the performance test report required by Minn. R. 7017.2035, subp. 1.


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation The emission factor used for calculating emissions shall be re-set to the 3-hour average emission rate in lbs/hr for EQUI 13, and shall be re-set to the emission rate in lbs/ton of BLS for EQUI 945, measured during the most recent MPCA-approved emission factor performance test. The new emission factor used for calculating 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. 7017.2025, Title I Condition: 40 CFR 52.21(o)(visibility) & Minn. R. 7007.3000]

COMG 6 GP340 LVHC NCG

Incineration and Venting

5.3.1 HAP Control: Gases from the LVHC (low volume, high concentration) system (COMG 6) shall be combusted in the lime kiln (TREA 16), or Boilers #2 or #1 (TREA 19 and TREA 18) as backup. [40 CFR 63.443(a)(1)(i), 40 CFR 63.443(d)(4)]

5.3.2 Enclosures and Venting: All equipment listed in this COMG shall be enclosed and vented into a closed-vent system meeting the requirements specified in 40 CFR Section 63.450 and as described below. [40 CFR 63.443(c), Minn. R. 7011.7700]

5.3.3 NCG (non-condensable gas) (LVHC) Venting: The Permittee shall control NCG (LVHC) through thermal oxidation in either the Lime Kiln (primary device), Power Boiler #2 (secondary device) or Power Boiler #1 (tertiary device). When none of these control devices is available, the Permittee may vent NCG (LVHC) directly to atmosphere. Upon venting NCG (LVHC) in an uncontrolled manner, the Permittee shall initiate investigation of the cause and take necessary action to re-establish control. If control cannot be re-established within 30 minutes, the Permittee shall initiate shutdown of the NCG (LVHC)-emitting sources in a controlled manner. The NCG (LVHC)-emitting sources, except for the evaporators, shall be shut down within 30 minutes and the remaining sources (the evaporators) shall be shutdown within two hours. The Permittee shall not re-start any of the NCG (LVHC) emitting sources until one of the control systems is operational. [Minn. R. 7007.0800, subp. 2]

5.3.4 TRS Control: Gases from the NCG (LVHC) sources (batch digester system (blow heat recovery), relief condensers and decant system, foul condensate stripper feed tank,


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation and the multiple-effect evaporator) shall be combusted in the lime kiln which shall be equipped with a scrubber. The TRS limit from the lime kiln shall be 8 ppmvd corrected to 10% oxygen. [40 CFR 60.283(a)(1)(i), Minn. R. 7011.2450]

5.3.5 Hours <= 30 hours per year 12-month rolling sum to be calculated by the 15th of each month of NCG (LVHC) Venting (venting directly to the atmosphere, rather than being oxidized in the lime kiln or Boilers #1 or #2). [Minn. R. 7007.0800, subps. 4-5, Title I Condition: 40 CFR pt. 52, 21(j)(BACT) & Minn. R. 7007.3000]

5.3.6 Sulfur Dioxide <= 115 tons per year 12-month rolling sum, Boilers #1 and #2 shall be combined, on a 12-month rolling sum basis. TRS Control - Backup and Emergency: During shutdowns and malfunctions of the lime kiln, non-condensable gases from the NCG (LVHC) sources (batch digester system, relief condensers and decant system, foul condensate stripper feed tank, and the multiple-effect evaporator system) shall be routed to Boiler #2 (TREA 19) for oxidation. During emergency situations when neither the lime kiln (TREA 16) or Boiler #2 (TREA 19) are available, the NCG shall be oxidized in Boiler #1 (TREA 18). NCG oxidation in Boilers #1 and #2, in aggregate, shall be limited to allow emissions of SO2 to no more than 115 tons per year from Boilers #1 and #2 together. [Title I Condition: 40 CFR 52.21(j)(BACT ) & Minn. R. 7007.3000]

5.3.7 Daily Recordkeeping. On each day of operation, the Permittee shall calculate, record, and maintain a record of the total hours of: a) hours during which NCG (LVHC) are oxidized in Boiler #1 or #2 b) NCG venting hours. [Minn. R. 7007.0800, subp. 5, Title I Condition: 40 CFR 52.21(j)(BACT) and Minn. R. 7007.3000]

5.3.8 Monthly Recordkeeping. By the 15th of the month, the Permittee shall calculate and record the following: 1) The total NCG venting hours for the previous calendar month using the daily records; and 2) The 12-month rolling sum of NCG venting hours for the previous 12-month period by summing the monthly hours of venting for the previous 12 months; and 1) the calculation of SO2 emissions from Boiler #1 and #2 for the previous month; and 2) The 12-month rolling sum of SO2 emissions from Boiler #1 and #2 for the previous 12-month period. (Boiler #1 SO2 emissions shall be calculated using emission factors and operating data, including hours of


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation NCG (LVHC) oxidation. Boiler #2 SO2 emissions shall be calculated using SO2 CEMS data and boiler operating data, including hours of NCG (LVHC) oxidation). [Minn. R. 7007.0800, subps. 4-5]

COMG 7 GP421 Kraft Pulping

Process Condensates

5.4.1 COMG 7 includes EQUIs 31, 34, 37, 961, STRUs 108 and 109, and TREA 38. The pulping process condensates from the following equipment systems shall be treated to meet the requirements below: - Each digester system; - Each turpentine recovery system; - Each evaporator system condensate from: (i) The vapors from each stage where weak liquor is introduced (feed stages); and (ii) Each evaporator vacuum system for each stage where weak liquor is introduced (feed stages) - Each HVLC collection system; and - Each LVHC collection system. The pulping process condensates from equipment systems listed above that in total contain a total HAP mass of 5.5 kilograms or more of total HAP per megagram (11.1 pounds per ton) of ODP (oven-dried pulp) for mills that perform bleaching shall be subject to the requirements in 40 CFR Section 63.446(d) and (e). (see 40 CFR Section 63.457(g) for condensate HAP concentration measurement). [40 CFR 63.446(c), Minn. R. 7011.7700]

5.4.2 The Permittee shall collect HAPs - Total >= 11.1 pounds per ton of ODP (oven-dried pulp) that are contained in the pulping process condensates from the equipment described above. [40 CFR 63.446(c)(3), Minn. R. 7011.7700]

5.4.3 Condensate Treatment - HAPs: Regulated condensates shall be hardpiped to the UNOX closed biological treatment system. The UNOX treatment system shall be operated in a manner that treats the collected condensate according to the following methods: - Discharge the pulping process condensate below the liquid surface of the UNOX biological treatment system and treat the pulping process condensates, and - Treat to reduce or destroy the total HAPs by 92% or more by weight, or at least 10.2 pounds of total HAP per ton of ODP. [40 CFR 63.446(e)(2),(3),&(5), Minn. R.


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation 7011.7700]

5.4.4 Condensate Closed Collection System: Regulated condensates shall be collected and conveyed in a closed collection system that is designed and operated to meet the requirements of 40 CFR Section 63.446(c) and 40 CFR Section 63.962(a)(2). [40 CFR 63.446, 40 CFR 63.962(a)(2), Minn. R. 7011.7700]

5.4.5 Condensate Monitoring Requirements: The Permittee shall use the average MLVSS measured during the most recent performance test of the UNOX system, that demonstrates compliance, as the minimum MLVSS demonstrating continuous compliance during subsequent operation. The Permittee shall operate the UNOX system in a manner consistent with the minimum MLVSS. EPA letter dated August 14, 2002, approved alternative monitoring. See Appendix F. [40 CFR 63.453, Minn. R. 7007.0800, subp. 4, Minn. R. 7011.7700]

5.4.6 Daily Recordkeeping. On each day of operation, the Permittee shall, using methods outlined in Appendix C to 40 CFR pt. 63, calculate, record, and maintain a record of the mixed liquor volatile suspended solids (MLVSS) concentration, in grams/Liter, in the UNOX system. [Minn. R. 7007.0800, subp. 5]

5.4.7 Reporting: Operation of the UNOX system below the minimum MLVSS shall constitute a violation of emissions standards in 40 CFR pt. 63, subp. S and shall be reported as a period of excess emissions. Report any/all excess emissions quarterly within 30 days following the end of the calendar quarter. The report must contain the required elements specified in 40 CFR Section 63.10(c). [40 CFR 63.455, Minn. R. 7007.0800, subp. 6, Minn. R. 7011.7700]

COMG 8 GP423 HVLC NCG


5.5.1 Hopper flush tank (EQUI 950), rapid drain tank (EQUI 951), precipitator salt-cake mix tank (EQUI 956), 55% BLS tank (EQUI 957), HL swing tank (EQUI 958), 72% BLS tank (EQUI 959), and 62% BLS tank (EQUI 978) shall be controlled with COMG 8 through gas combustion, but are not subject to Section 63, Subpart S. [Minn. R. 7007.0800, subp. 2]

5.5.2 Periods of excess emissions reported under 40 CFR Section 63.455 shall not be a violation of 40 CFR Section 63.443 (c) and (d) provided that the time of excess emissions (excluding periods of startup, shutdown, or malfunction) divided by the total process operating time in a semi-annual reporting period does not exceed four percent for control devices used to reduce the total


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation HAP emissions from the HVLC system. [40 CFR 63.443, Minn. R. 7011.7700]

5.5.3 Enclosures and Venting: All equipment subject to 40 CFR pt. 63, subp. S listed in this COMG shall be enclosed and vented into a closed-vent system meeting the requirements specified in 40 CFR Section 63.450. [40 CFR 63.443(c), Minn. R. 7011.7700]

5.5.4 COMG 8 gases shall be combusted in the Recovery Furnace (TREA 17), which is subject to 40 CFR Section 60.283(a)(2). [40 CFR 60.283(a), Minn. R. 7011.7700]

COMG 11 GP429 ClO2 Generator 5.6.1 The Permittee shall limit emissions of Chlorine <= 0.17

pounds per hour 3-hour average, as determined by performance test. (Limit established due to risk assessment performed as part of PSD permitting for 1989 permit, number 102A-89-OT-2). [Minn. R. 7007.0800, subp. 2]

5.6.2 The Permittee shall limit emissions of Chlorine Dioxide <= 2.2 pounds per hour 3-hour average, as determined by performance test. (Limit established due to risk assessment performed as part of PSD permitting for 1989 permit, number 102A-89-OT-2). [Minn. R. 7007.0800, subp. 2]

5.6.3 The Permittee shall vent emissions from COMG 11 to TREA 12 whenever COMG 11 operates, and operate and maintain TREA 12 at all times that any emissions are vented to TREA 12. The Permittee shall document periods of non-operation of the control equipment. Additional requirements are listed at TREA 12. [Minn. R. 7007.0800, subp. 14, Minn. R. 7007.0800, subp. 2]

COMG 12 GP430 Bleach Plant 5.7.1 The Permittee shall limit emissions of HAPs - Total <= 10

parts per million or less than or equal to 0.02 lb per ton of oven-dried pulp or reduce the Total Chlorinated HAP mass entering the control device by 99% or more by weight. Here, Total HAPs refers to Total Chlorinated HAPs (not including chloroform) based on the sum of all individual chlorinated HAPs or as chlorine. [40 CFR 63.445(c), Minn. R. 7011.7700]

5.7.2 The Permittee shall limit emissions of Chlorine <= 0.41 pounds per hour 3-hour average, as determined by performance test. [Minn. R. 7007.0800, subp. 2]

5.7.3 The Permittee shall limit emissions of Chlorine Dioxide <= 1.2 pounds per hour 3-hour average, as determined by performance test. [Minn. R. 7007.0800, subp. 2]

5.7.4 The Permittee shall comply with paragraph (d)(1) or (d)(2) of 40 CFR Section 63.445 (summarized below) to


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation reduce chloroform air emissions to the atmosphere. The Permittee shall comply with the following: (1) Comply with the applicable effluent limitation guidelines and standards specified in 40 CFR pt. 430; (2) Use no hypochlorite or chlorine for bleaching in the bleaching system or line. [40 CFR 63.445(d), Minn. R. 7011.7700]

5.7.5 Enclosures and Venting: Equipment listed at STRU 75, and which are associated with equipment where bleaching chemicals are added, shall be enclosed and vented into a closed-vent system meeting the requirements specified in 40 CFR Section 63.450. [40 CFR 63.443(c), Minn. R. 7011.7700]

5.7.6 Control Equipment Operation: (Additional requirements listed at TREA 13) The Permittee shall operate the gas scrubber (TREA 13) in a manner consistent with the minimum or maximum (as appropriate) operating parameter value or procedure required to be monitored under 40 CFR Section 63.453(a) through (n), as established by performance test, and as described in 40 CFR Section 63.453(o). Operation of the control device below minimum operating parameter values or above maximum operating parameter values established under 40 CFR pt. 63, subp. S shall constitute a violation of the applicable emission standard of 40 CFR pt. 63, subp. S and shall be reported as a period of excess emissions. [40 CFR 63.453(o), Minn. R. 7011.7700]

COMG 13 GP431 40 CFR pt. 63,

subp. DDDDD Requirements

5.8.1 Subject Items subject to 40 CFR pt. 63, subp. DDDDD: Boiler #1 (EQUI 15), Boiler #2 (EQUI 16), Boiler #3 (EQUI 17), and Boiler #9 (EQUI 18). All submittals and notifications under 40 CFR pt. 63, subp. DDDDD shall be sent to both the MPCA and EPA contacts listed on Page 4 of this permit, unless otherwise noted. [Minn. R. 7007.0800, subp. 2]

5.8.2 The MPCA does not have delegation for this standard, but MPCA must be copied on all submittals/notifications. [Minn. R. 7007.0800, subp. 2]

5.8.3 The Permittee must conduct a tune-up of the boiler or process heater annually as specified in 40 CFR Section 63.7540(a)(10) beginning January 31, 2016. [40 CFR 63.7500(a)(1), Table 3]

5.8.4 Each annual tune-up specified in 40 CFR Section 63.7540(a)(10) must be no more than 13 months after the previous tune-up. This frequency does not apply to units with continuous oxygen trim systems that maintain an optimum air to fuel ratio. [40 CFR


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation 63.7515(d), 40 CFR 63.7540(a)(10)]

5.8.5 The Permittee must conduct an annual tune-up of the boiler or process heater to demonstrate continuous compliance as specified below: 1. As applicable, inspect the burner, and clean or replace any components of the burner as necessary (the Permittee may delay the burner inspection until the next scheduled unit shutdown). Units that produce electricity for sale may delay the burner inspection until the first outage, not to exceed 36 months from the previous inspection. At units where entry into a piece of process equipment or into a storage vessel is required to complete the tune-up inspections, inspections are required only during planned entries into the storage vessel or process equipment; 2. Inspect the flame pattern, as applicable, and adjust the burner as necessary to optimize the flame pattern. The adjustment should be consistent with the manufacturer's specifications, if available; 3. Inspect the system controlling the air-to-fuel ratio, as applicable, and ensure that it is correctly calibrated and functioning properly (the Permittee may delay the inspection until the next scheduled unit shutdown). Units that produce electricity for sale may delay the inspection until the first outage, not to exceed 36 months from the previous inspection; 4. Optimize total emissions of CO. This optimization should be consistent with the manufacturer's specifications, if available, and with any NOx requirement to which the unit is subject; 5. Measure the concentrations in the effluent stream of CO in parts per million, by volume, and oxygen in volume percent, before and after the adjustments are made (measurements may be either on a dry or wet basis, as long as it is the same basis before and after the adjustments are made). Measurements may be taken using a portable CO analyzer; and 6. Maintain on-site and submit, if requested by the Administrator, an annual report containing the information below: i. The concentrations of CO in the effluent stream in parts per million by volume, and oxygen in volume percent, measured at high fire or typical operating load, before and after the tune-up of the boiler or process heater; ii. A description of any corrective actions taken as a part


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation of the tune-up; and iii. The type and amount of fuel used over the 12 months prior to the tune-up, but only if the unit was physically and legally capable of using more than one type of fuel during that period. Units sharing a fuel meter may estimate the fuel used by each unit. [40 CFR 63.7540(a)(10)]

5.8.6 If the unit is not operating on the required date for a tune-up, the tune-up must be conducted within 30 calendar days of startup. [40 CFR 63.7515(g), 40 CFR 63.7540(a)(13)]

5.8.7 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. Determination of whether such operation and maintenance procedures are being used will be based on information available to the Administrator that may include, but is not limited to, monitoring results, review of operation and maintenance procedures, review of operation and maintenance records, and inspection of the source. [40 CFR 63.7500(a)(3)]

5.8.8 Assertion of Affirmative Defense: To establish the affirmative defense in any action to enforce such a standard, The Permittee must timely meet the reporting requirements in 40 CFR Section 63.7501(b), and must prove by a preponderance of evidence the items described in 40 CFR Section 63.7501(a). [40 CFR 63.7501(a)]

5.8.9 The Permittee seeking to assert an affirmative defense shall submit a written report to the Administrator with all necessary supporting documentation, that it has met the requirements set forth in 40 CFR Section 63.7500. This affirmative defense report shall be included in the first periodic compliance, deviation report or excess emission report otherwise required after the initial occurrence of the violation of the relevant standard (which may be the end of any applicable averaging period). If such compliance, deviation report or excess emission report is due less than 45 days after the initial occurrence of the violation, the affirmative defense report may be included in the second compliance, deviation report or excess emission report due after the initial occurrence of the violation of the relevant standard. [40 CFR 63.7501(b)]

5.8.10 A Compliance Report must contain the following: 1. Information required in 40 CFR Section 63.7550(c)(1) through (5);


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation 2. If there were no deviations from the requirements for work practice standards in Table 3 of 40 CFR pt. 63, subp. DDDDD that apply, a statement that there were no deviations from the work practice standards during the reporting period; and 3. If there was a deviation from a work practice standard during the reporting period, the report must contain the information in 40 CFR Section 63.7550(d). [40 CFR 63.7550(b), 40 CFR 63.7550(a), Table 9]

5.8.11 A compliance report must contain the following information: 1. Company and Facility name and address. 2. Process unit information, emissions limitations, and operating parameter limitations. 3. Date of report and beginning and ending dates of the reporting period. 4. The total operating time during the reporting period. 5. Include the date of the most recent tune-up for each unit subject to only the requirement to conduct a biennial tune-up. Include the date of the most recent burner inspection if it was not done biennially and was delayed until the next scheduled or unscheduled unit shutdown. [40 CFR 63.7550(c)]

5.8.12 For each deviation from an emission limit or operating limit in 40 CFR pt. 63, subp. DDDDD that occurs at an individual boiler or process heater where a CMS is not used to comply with that emission limit or operating limit, the compliance report must additionally contain the following information: 1. A description of the deviation and which emission limit or operating limit from which there was a deviation. 2. Information on the number, duration, and cause of deviations (including unknown cause), as applicable, and the corrective action taken. 3. If the deviation occurred during an annual performance test, provide the date the annual performance test was completed. [40 CFR 63.7550(d)]

5.8.13 Records to Keep. The Permittee must keep records of the occurrence and duration of each malfunction of the boiler or of the associated air pollution control and monitoring equipment. [40 CFR 63.7555(d)(7), Minn. R.



5.8.14 Records to Keep. The Permittee must keep records of actions taken during periods of malfunction to minimize emissions in accordance with the general duty to minimize emissions in 40 CFR Section 63.7500(a)(3), including corrective actions to restore the malfunctioning boiler, air pollution control, or monitoring equipment to its normal or usual manner of operation. [40 CFR 63.7555(d)(8), Minn. R. 7011.7050]

5.8.15 If a malfunction occurred during the reporting period, the report must include the number, duration, and a brief description for each type of malfunction which occurred during the reporting period and which caused or may have caused any applicable emission limitation to be exceeded. The report must also include a description of actions taken by the Permittee during a malfunction of a boiler, process heater, or associated air pollution control device or CMS to minimize emissions in accordance with Section 63.7500(a)(3), including actions taken to correct the malfunction. [40 CFR 63.7550(c)(5)(xiii), Minn. R. 7011.7050]

5.8.16 The Permittee must comply with all applicable requirements of 40 CFR pt. 63, subp A, as follows: 63.4(b), 63.5(b)(4), 63.5(b)(6), 63.6(f)(2-3), 63.8(a)(2), 63.8(c)(1-8), 63.8(d), 63.8(e), 63.8(g), 63.9(f), 63.9(g), 63.9(h), 63.9(j), 63.10(a), 63.10(b)(1), 63.10(b)(2)(i), 63.10(b)(2)(iii), 63.10(b)(2)(vi-xiv), 63.10(c), 63.10(d)(1), 63.10(d)(4), 63.10(e)(1-2), 63.10(e)(3)(i-vii), and 63.10(e)(4). A copy of 40 CFR pt. 63, subp. A is included in Appendix J. If the standard changes or 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. [40 CFR 63.7565, 40 CFR pt. 63, subp. A , Minn. R. 7007.0400, subp. 3, Minn. R. 7007.1150-7007.1500, Minn. R. 7011.7000]

COMG 14 GP432 40 CFR pt. 63,

subp. S Requirements

5.9.1 Subject Items subject to 40 CFR pt. 63, subp. S: EQUI 2, EQUI 3, EQUI 9, EQUI 13, EQUI 15, EQUI 16, EQUI 31, EQUI 32, EQUI 33, EQUI 34, EQUI 36, EQUI 37, EQUI 44, EQUI 64, EQUI 65, EQUI 66, EQUI 67, EQUI 71, EQUI 950, EQUI 951, EQUI 952, EQUI 956, EQUI 957, EQUI 958, EQUI 959, EQUI 961, EQUI 966, EQUI 967, EQUI 968,


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation EQUI 972, EQUI 973, EQUI 974, EQUI 975, EQUI 976, EQUI 977, EQUI 978, EQUI 979, EQUI 938, EQUI 939, TREA 13, TREA 16, TREA 17, TREA 18, TREA 19. The Permittee must submit notification according to 40 CFR Section 63.9(b) if the Permittee constructs or reconstructs a source such that the source becomes an affected source subject to a standard. [40 CFR 63.5(b)(4), Minn. R. 7011.7000]

5.9.2 At all times, the owner or operator 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. 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 63.453(q), Minn. R. 7011.7700]

5.9.3 Standards for Enclosures and Closed-vent Systems: Each enclosure shall maintain negative pressure at each enclosure or hood opening as demonstrated by procedures specified in 40 CFR Section 63.457(e). Each enclosure or hood opening closed during the initial performance test specified in 40 CFR Section 63.457(a) shall be maintained in the same closed and sealed position as during the performance test at all times except when necessary to use the opening for sampling, inspection, maintenance, or repairs. Each component of the closed-vent system used to comply with 40 CFR Section 63.443(c) and 63.445(b) that is operated at positive pressure and located prior to a control device shall be designed for and operated with no detectable leaks as indicated by an instrument reading of less than 500 ppm by volume above background, as measured by the procedures in 40 CFR Section 63.457(d). Each bypass line in the closed-vent system that could divert vent streams containing HAP to the atmosphere without meeting the emission limitations in 40 CFR Section 63.443 or 63.445 shall comply with either of the following requirements: 1) On each bypass line, the owner or operator shall install, calibrate, maintain and operate according to manufacturer's specifications a flow indicator that provides a record of the presence of gas stream flow in the bypass line at least once every 15 minutes. The flow indicator shall be installed in the bypass line in such a way as to indicate flow in the bypass line; or 2) For bypass line valves that are not computer


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation controlled, the owner or operator shall maintain the bypass line valve in the closed position with a car seal or a seal placed on the valve or closure mechanism in such a way that valve or closure mechanism cannot be opened without breaking the seal. [40 CFR 63.450(b), Minn. R. 7011.7700]

5.9.4 Performance tests shall be conducted under such conditions as the Administrator specifies to the owner or operator based on representative performance of the affected source for the period being tested. Upon request, the owner or operator shall make available to the Administrator such records as may be necessary to determine the conditions of performance tests. [40 CFR 63.457(o), Minn. R. 7011.7700]

5.9.5 To establish or reestablish the value for each operating parameter required to be monitored under paragraphs (b) through (j), (l), and (m) of 63.453 or to establish appropriate parameters for paragraphs (f), (i), (j)(2), and (m) of 63.453, each owner or operator shall use the following procedures: Provide for the Administrator's approval the rationale for the selected operating parameter value, and monitoring frequency, and averaging time. Include all data and calculations used to develop the value and a description of why the value, monitoring frequency, and averaging time demonstrate continuous compliance with the applicable emission standard. [40 CFR 63.453(n)(4)]

5.9.6 Monitoring Requirements for Enclosure and Closed-vent Systems: 1) For each enclosure opening, a visual inspection of the closure mechanism specified in 40 CFR Section 63.450(b) shall be performed at least once every calendar month with at least 21 days elapsed between inspections to ensure the opening is maintained in the closed position and sealed. 2) Each closed-vent system required by 40 CFR Section 63.450(a) shall be visually inspected at least once every calendar month with at least 21 days elapsed between inspections and at other times as requested by the Administrator. The visual inspection shall include inspection of ductwork, piping, enclosures and connections to covers for visible evidence of defects. 3) For positive pressure closed-vent systems or portions of closed-vent systems, demonstrate no detectable leaks as specified in 40 CFR Section 63.450(c) measured initially and annually by the procedures in 40 CFR Section 63.457(d). 4) Demonstrate initially and annually that each enclosure opening is maintained at negative pressure as specified in 40 CFR Section 63.457(e).


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation 5) The valve or closure mechanism specified in 40 CFR Section 63.450(d)(2) shall be inspected at least once every calendar month with at least 21 days elapsed between inspections to ensure that the valve is maintained in the closed position and the emission point gas stream is not diverted through the bypass line. 6) If an inspection required by paragraphs 1 through 5 of this section identified visible defects in ductwork, piping or enclosure or connections to covers required by 40 CFR Section 63.450, or if an instrument reading of 500 ppm by volume or greater above background is measured, or if enclosure openings are not maintained at negative pressure, then the following corrective actions shall be taken as soon as practicable: (i) A first effort to repair or correct the closed-vent system shall be made as soon as practicable but no later than 5 calendar days after the problem is identified. (ii) The repair or corrective action shall be completed no later than 15 calendar days after the problem is identified. [40 CFR 63.453(k), Minn. R. 7011.7700]

5.9.7 Recordkeeping of malfunctions. The owner or operator must maintain the following records of malfunctions: (1) Records of the occurrence and duration of each malfunction of operation (i.e., process equipment) or the air pollution control and monitoring equipment. (2) Records of actions taken during periods of malfunction to minimize emissions in accordance with 63.453(q), including corrective actions to restore malfunctioning process and air pollution control and monitoring equipment to its normal or usual manner of operation. [40 CFR 63.454(g), Minn. R. 7011.7700]

5.9.8 Site-Specific Inspection Plan: The Permittee shall prepare and maintain a site-specific inspection plan for each applicable enclosure opening, closed-vent system, and closed collection system. The Plan shall include a drawing or schematic of the components of applicable affected equipment. The Permittee shall record the information described in 40CFR Section 63.454(b) for each inspection. [40 CFR 63.454(b), Minn. R. 7011.7700]

5.9.9 Malfunction reporting requirements. If a malfunction occurred during the reporting period, the report must include the number, duration and a brief description for each type of malfunction which occurred during the reporting period and which caused or may have caused any applicable emission limitation to be exceeded. The report must also include a description of actions taken by an owner or operator during a malfunction of an affected source to minimize emissions in accordance with 40 CFR Section 63.453(q), including actions taken to correct a malfunction. [40 CFR 63.455(g), Minn. R. 7011.7700]


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation 5.9.10 The Permittee must comply with all applicable

requirements of 40 CFR pt. 63, subp A, as follows: 63.4(b), 63.5(b)(6), 63.6(f)(2-3), 63.7(b), 63.7(c)(2-3), 63.7(d), 63.7(e)(2-3), 63.7(g), 63.7(h), 63.8(a)(2), 63.8(b)(1), 63.8(c)(1)(i-ii), 63.8(c)(2-3), 63.8(c)(6), 63.8(c)(7)(i-ii), 63.8(c)(8), 63.8(d)(1-3), 63.8(e), 63.8(f)(1-5), 63.8(g), 63.9(e), 63.9(g)(1), 63.9(h), 63.9(j), 63.10(a), 63.10(b)(1), 63.10(b)(2)(iii), 63.10(b)(2)(vi-xiv), 63.10(c)(1), 63.10(c)(5)-(8), 63.10(c)(12)-(14), 63.10(d)(2), 63.10(d)(4), 63.10(e)(1-2(i)), and 63.10(e)(3)(i-vii). A copy of 40 CFR pt. 63, subp. A is included in Appendix J. If the standard changes or 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. [40 CFR pt. 63, subp. A, 40 CFR pt. 63, subp. S, Minn. R. 7007.0400, subp. 3, Minn. R. 7007.1150-7007.1500, Minn. R. 7011.7000]

COMG 15 GP433 40 CFR pt. 63,

subp. MM Requirements

5.10.1 Subject Items subject to 40 CFR pt. 63, subp. MM: EQUI 9, EQUI 13, EQUI 945, TREA 1, TREA 2, TREA 3, TREA 4, TREA 15, TREA 16, TREA 17. The Permittee must submit notification according to 40 CFR Section 63.9(b) if the Permittee constructs or reconstructs a source such that the source becomes an affected source subject to a standard. [40 CFR 63.5(b)(4), Minn. R. 7011.7000]

5.10.2 The owner or operator complying through the use of an NDCE recovery furnace equipped with a dry ESP system is not required to conduct any performance testing to demonstrate compliance with the gaseous organic HAP standard. [40 CFR 63.865(c)(1), Minn. R. 7011.7700]

5.10.3 See 40 CFR Section 63.860 for applicability requirements. [40 CFR 63.860, Minn. R. 7011.7700]

5.10.4 The Permittee must comply with all applicable requirements of 40 CFR pt. 63, subp A, as follows: 63.4(b), 63.5(b)(6), 63.6(e)(1)(i-ii), 63.6(e)(3(i)), 63.6(e)(3)(iii-ix), 63.6(f)(1-3), 63.6(h)(1-2), 63.6(h)(4-9), 63.7(b), 63.7(c)(2-3), 63.7(d), 63.7(e)(1-3), 63.7(g), 63.7(h), 63.8(a)(2), 63.8(b)(1-2), 63.8(c)(1-6), 63.8(c)(7)(i-ii), 63.8(c)(8), 63.8(d), 63.8(e), 63.8(g), 63.9(e), 63.9(g), 63.9(h), 63.9(j), 63.10(a), 63.10(b)(1-2),


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation 63.10(c), 63.10(d)(1), 63.10(d)(3-4), 63.10(d)(5)(i-ii), 63.10(e)(1-2), 63.10(e)(3)(i-vii), and 63.10(e)(4). A copy of 40 CFR pt. 63, subp. A is included in Appendix J. If the standard changes or 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. [40 CFR pt. 63, subp. A, 40 CFR pt. 63, subp. MM, Minn. R. 7007.0400, subp. 3, Minn. R. 7007.1150-7007.1500, Minn. R. 7011.7000]

COMG 16 GP434 Internal

Combustion Engines

5.11.1 Subject Items subject to 40 CFR pt. 63, subp. ZZZZ: EQUI 941, EQUI 942, and EQUI 943. If the permittee has an existing non-emergency CI stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, an existing stationary CI RICE with a site rating of less than or equal to 500 brake HP located at a major source of HAP emissions, or an existing stationary CI RICE located at an area source of HAP emissions, the permittee must comply with the applicable emission limitations, operating limitations, and other requirements no later than May 3, 2013. If the permittee has an existing stationary SI RICE with a site rating of less than or equal to 500 brake HP located at a major source of HAP emissions, or an existing stationary SI RICE located at an area source of HAP emissions, the permittee must comply with the applicable emission limitations, operating limitations, and other requirements no later than October 19, 2013. [40 CFR 63.6595(a), Minn. R. 7011.2305, Minn. R. 7011.2310]

5.11.2 If the permittee owns or operates an existing stationary RICE with a site rating of equal to or less than 500 brake HP located at a major source of HAP emissions, the permittee must comply with the emission limitations and other requirements in Table 2c to this subpart which apply to the permittee. [40 CFR 63.6602, Minn. R. 7011.2305, Minn. R. 7011.2310]

5.11.3 For each emergency stationary CI RICE and black start stationary CI RICE, the Permittee must meet the following requirements, except during periods of startup: 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


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation annually, whichever comes first, and replace as necessary; c. Inspect all hoses and belts every 500 hours of operation or annually, whichever comes first, and replace as necessary. During periods of startup, the Permittee must minimize the engine's time spent at idle and minimize the engine's startup time at startup to a period needed for appropriate and safe loading of the engine, not to exceed 30 minutes, after which time the non-startup emission limitations apply. [40 CFR 63.6602, 40 CFR pt. 63, subp. ZZZZ (Table 2c), Minn. R. 7011.2305, Minn. R. 7011.2310]

5.11.4 For each emergency stationary SI RICE and black start stationary SI RICE, the Permittee must meet the following requirement, except during periods of startup: a. Change oil and filter every 500 hours of operation or annually, whichever comes first; b. Inspect spark plugs every 1,000 hours of operation or annually, whichever comes first, and replace as necessary; c. Inspect all hoses and belts every 500 hours of operation or annually, whichever comes first, and replace as necessary. During periods of startup, the Permittee must minimize the engine's time spent at idle and minimize the engine's startup time at startup to a period needed for appropriate and safe loading of the engine, not to exceed 30 minutes, after which time the non-startup emission limitations apply. [40 CFR 63.6602, 40 CFR pt. 63, subp. ZZZZ (Table 2c), Minn. R. 7011.2305, Minn. R. 7011.2310]

5.11.5 If an emergency engine is operating during an emergency and it is not possible to shut down the engine in order to perform the work practice requirements on the schedule required in Table 2c of this subpart, or if performing the work practice on the required schedule would otherwise pose an unacceptable risk under federal, state, or local law, the work practice can be delayed until the emergency is over or the unacceptable risk under federal, state, or local law has abated. The work practice should be performed as soon as practicable after the emergency has ended or the unacceptable risk under federal, state, or local law has abated. Sources must report any failure to perform the work practice on the schedule required and the federal, state or local law under which the risk was deemed unacceptable.


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation Sources have the option to utilize an oil analysis program as described in 63.6625(i) or (j) in order to extend the specified oil change requirement in Table 2c of subpart ZZZZ. [40 CFR 63.6602, 40 CFR pt. 63, subp. ZZZZ (Table 2c), Minn. R. 7011.2305, Minn. R. 7011.2310]

5.11.6 a) The Permittee must be in compliance with the emission limitations, operating limitations, and other requirements in this subpart that apply to you at all times. (b) 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, Minn. R. 7011.2305, Minn. R. 7011.2310]

5.11.7 (a) The Permittee must demonstrate continuous compliance with each emission limitation, operating limitation, and other requirements in Tables 1a and 1b, Tables 2a and 2b, Table 2c, and Table 2d to this subpart that apply to you according to methods specified in Table 6 to this subpart. (b) The Permittee must report each instance in which the Permittee did not meet each emission limitation or operating limitation in Tables 1a and 1b, Tables 2a and 2b, Table 2c, and Table 2d to this subpart that apply to you. These instances are deviations from the emission and operating limitations in this subpart. These deviations must be reported according to the requirements in 63.6650. [40 CFR 63.6640(a)(b), Minn. R. 7011.2305, Minn. R. 7011.2310]

5.11.8 For each existing emergency and black start stationary RICE less than or equal to 500 HP located at a major source of HAPs, complying with the requirement to Work or Management practices, the Permittee must demonstrate continuous compliance by: i. Operating and maintaining the stationary RICE according to the manufacturer's emission-related operation and maintenance instructions; or


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation ii. Develop and follow a maintenance plan which must provide to the extent practicable for the maintenance and operation of the engine in a manner consistent with good air pollution control practice for minimizing emissions. [40 CFR pt. 63, subp. ZZZZ(Table 6), Minn. R. 7011.2305, Minn. R. 7011.2310]

5.11.9 If the Permittee owns or operates an emergency stationary RICE, the Permittee must operate the emergency stationary RICE according to the requirements in paragraphs (f)(1) through (4) of this section. In order for the engine to be considered an emergency stationary RICE 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 paragraphs (f)(1) through (4) of this section, is prohibited. If the Permittee does not operate the engine according to the requirements in paragraphs (f)(1) through (4) of this section, 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 RICE in emergency situations. (2) The Permittee may operate the emergency stationary RICE for any combination of the purposes specified in paragraphs (f)(2)(i) through (iii) of this section for a maximum of 100 hours per calendar year. Any operation for non-emergency situations as allowed by paragraphs (f)(3) and (4) of this section counts as part of the 100 hours per calendar year allowed by this paragraph (f)(2). (i) Emergency stationary RICE 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 owner or operator 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 owner or operator maintains records indicating that federal, state, or local standards require maintenance and testing of emergency RICE beyond 100 hours per calendar year. (ii) Emergency stationary RICE may be operated for emergency demand response for periods in which the


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation Reliability Coordinator under the North American Electric Reliability Corporation (NERC) Reliability Standard EOP-002-3, Capacity and Energy Emergencies (incorporated by reference, see Â§63.14), 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 RICE may be operated for periods where there is a deviation of voltage or frequency of 5 percent or greater below standard voltage or frequency. 3) Emergency stationary RICE located at major sources of HAP 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 paragraph (f)(2) of this section. The 50 hours per year for non-emergency situations cannot be used for peak shaving or non-emergency demand response, or to generate income for a facility to supply power to an electric grid or otherwise supply power as part of a financial arrangement with another entity. [40 CFR 63.6640(f), Minn. R. 7011.2305, Minn. R. 7011.2310]

5.11.10 a) If the Permittee must comply with the emission and operating limitations, the Permittee must keep the records described in paragraphs (a)(1) through (a)(5), (b)(1) through (b)(3) and (c) of this section. (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 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. (d) The Permittee must keep the records required in Table 6 of this subpart to show continuous compliance with each emission or operating limitation that applies. (e) The Permittee must keep records of the maintenance conducted on the stationary RICE in order to demonstrate that you operated and maintained the stationary RICE and after-treatment control device (if any) according to the maintenance plan.


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation (f) If the Permittee owns or operates any of the stationary RICE in paragraphs (f)(1) through (2) of this section, the Permittee must keep records of the hours of operation of the engine that is recorded through the non-resettable hour meter. The owner or operator 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. If the engine is used for the purposes specified in 40 CFR 63.6640(f)(2)(ii) or (iii) or 40 CFR 63.6640(f)(4)(ii), the owner or operator must keep records of the notification of the emergency situation, and the date, start time, and end time of engine operation for these purposes. (1) An existing emergency stationary RICE with a site rating of less than or equal to 500 brake HP located at a major source of HAP emissions that does not meet the standards applicable to non-emergency engines. [40 CFR 63.6655, Minn. R. 7011.2305, Minn. R. 7011.2310]

5.11.11 a) The Permittee's records must be in a form suitable and readily available for expeditious review according to 40 CFR 63.10(b)(1). (b) As specified in 40 CFR 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 63.10(b)(1). [40 CFR 63.6660, Minn. R. 7011.2305, Minn. R. 7011.2310]

5.11.12 The Permittee must also report each instance in which the applicable requirements were not met in Table 8 (General Provisions) to this subpart. [40 CFR 63.6640(e), Minn. R. 7011.2305, Minn. R. 7011.2310]

5.11.13 If the Permittee owns or operates any of the following stationary RICE, the Permittee must operate and maintain the stationary RICE 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 the engine in a manner consistent with good air pollution control practice for minimizing emissions: (1) An existing stationary RICE with a site rating of less than 100 HP located at a major source of HAP


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation emissions; (2) An existing emergency or black start stationary RICE with a site rating of less than or equal to 500 HP located at a major source of HAP emissions. [40 CFR 63.6625(e), Minn. R. 7011.2305, Minn. R. 7011.2310]

5.11.14 If the Permittee owns or operates an existing emergency stationary RICE with a site rating of less than or equal to 500 brake HP located at a major source of HAP emissions or an existing emergency stationary RICE located at an area source of HAP emissions, the Permittee must install a non-resettable hour meter if one is not already installed. [40 CFR 63.6625(f), Minn. R. 7011.2305, Minn. R. 7011.2310]

5.11.15 The Permittee must comply with all applicable requirements of 40 CFR pt. 63, subp A, as follows: 63.4(b), 63.5(b)(4), 63.5(b)(6), 63.6(f)(2-3), 63.7(d), 63.7(e)(3), 63.7(g), 63.7(h), 63.8(a)(2), 63.8(b)(1-2), 63.8(c), 63.8(c)(7)(i-ii), 63.8(c)(8), 63.8(d), 63.8(g), 63.9(j), 63.10(a), 63.10(b)(1), 63.10(b)(2)(vi-xiv), 63.10(c), 63.10(d)(1), 63.10(d)(4), 63.10(e)(1-2(i)), and 63.10(e)(3)(i-vii). A copy of 40 CFR pt. 63, subp. A is included in Appendix J. If the standard changes or 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. [40 CFR 63.6665, 40 CFR pt. 63, subp. A, Minn. R. 7007.0400, subp. 3, Minn. R. 7007.1150-7007.1500, Minn. R. 7011.7000]

5.11.16 Opacity <= 20 percent opacity once operating temperatures have been attained. This condition applies to each engine in COMG 16. [Minn. R. 7011.2300, subp. 1]

5.11.17 Sulfur Dioxide <= 0.50 pounds per million Btu heat input. [Minn. R. 7011.2300, subp. 2(A)]

5.11.18 Sulfur Dioxide <= 0.0015 pounds per million Btu heat input This limit is effective on January 31, 2018. [Minn. R. 7011.2300, subp. 2(B)]

5.11.19 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. [Minn. R. 7007.0800, subps. 4-5]

5.11.20 The Permittee shall keep records of fuel type and usage


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation on a monthly basis. [Minn. R. 7007.0800, subp. 5]

5.11.21 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]

COMG 19 Three

Causticizers, Lime Slaker

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

5.12.2 Particulate Matter <= 0.30 grains per dry standard cubic foot of exhaust gas unless required to further reduce emissions to comply with the less stringent limit of either Minn. R. 7011.0730 or Minn. R. 7011.0735. The units in COMG 19 are not expected to emit particulate matter. [Minn. R. 7011.0715, subp. 1(A)]

EQUI 9 EU320 Recovery

Furnace -Furnace

5.13.1 The Permittee shall limit emissions of Particulate Matter <= 27.0 pounds per hour 3-hour average, as determined by performance test. This is based on an EPA approved limit from a letter dated September 29, 2008. [40 CFR 63.862(a)(1)(ii), Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.13.2 The Permittee shall limit emissions of Particulate Matter <= 0.044 grains per dry standard cubic foot 3-hour average, as determined by performance test, @ 8% O2. This is the limit for both NSPS 40 CFR pt. 60, subp. BB and NESHAP 40 CFR pt. 63, subp. MM. [40 CFR 60.282(a)(i), 40 CFR 63.862(a)(1)(i), Minn. R. 7011.2450, Minn. R. 7011.7700]

5.13.3 The Permittee shall limit emissions of PM < 10 micron <= 19.2 pounds per hour 3-hour average, as determined by performance test. This is based on an EPA approved limit from a letter dated September 29, 2008. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.13.4 The Permittee shall limit Opacity <= 35 percent opacity 6-minute average (NSPS 40 CFR pt. 60, supb. BB limit). [40 CFR 60.282(a)(ii), Minn. R. 7011.2450]

5.13.5 The Permittee shall limit emissions of Sulfur Dioxide <= 200 tons per year 12-month rolling sum. The Permittee shall use the emission factor derived from the most recent performance test and the monthly production throughput. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation 5.13.6 The Permittee shall limit emissions of Sulfur Dioxide <=

106.2 pounds per hour 3-hour average, as determined by performance test. Compliance for this limit is demonstrated with a performance test. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.13.7 The Permittee shall limit emissions of Nitrogen Oxides <= 110 pounds per hour 30-day rolling average. This is equivalent to 80 ppm on a dry basis, corrected to 8% oxygen. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.13.8 The Permittee shall limit emissions of Carbon Monoxide <= 538 pounds per hour 24-hour rolling average. This is equivalent to 600 ppm on a dry basis, corrected to 8% oxygen. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.13.9 The Permittee shall limit emissions of Volatile Organic Compounds <= 31.3 pounds per hour 3-hour average, as determined by performance test, measured as carbon, excluding methane. (this limit is based on emission rate of 0.6 lb/salt cake free, bone dry tons of black liquor solids). [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.13.10 The Permittee shall limit emissions of Carbon Monoxide <= 2289 tons per year 12-month rolling average. [Title I Condition: Avoid major modification under 40 CFR 52.21(b)(2) & Minn. R. 7007.3000]

5.13.11 The Permittee shall limit emissions of Sulfur - Total Reduced including H2S <= 5 parts per million 12-hour average, calculated on a dry basis and corrected to 8% oxygen. This is the limit for both BACT and NSPS 40 CFR pt. 60, subp. BB. [40 CFR 60.283(a)(2), Minn. R. 7011.2450, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.13.12 The Permittee shall limit Sulfur Content of Fuel <= 0.050 percent by weight distillate oil sulfur content. [Minn. R. 7007.0800, subp. 2]

5.13.13 Fuels burned: The Permittee shall burn Natural Gas; HVLC NCGs and black liquor solids (BLS) (virgin bone dried basis) and BLS blended with distillate oil (#1 or #2) are also combusted in the recovery furnace. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

5.13.14 The Permittee shall limit Process Throughput <= 1595 tons per day of virgin black liquor solids (virgin bone dried basis), calculated on a twelve-hour block average, unless a new limit is set pursuant to Minn. R. 7017.2025, subp. 3, based on the most recent MPCA


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation approved performance test where compliance was demonstrated. The twelve-hour block average shall be calculated by dividing the total weight by the total operating time in each twelve-hour block. Down time of 15 or more minutes is not to be included as operating time. The Black Liquor Solids Production limit located at the TFAC level also applies at all times. [Minn. R. 7017.2025, subp. 3]

5.13.15 The Permittee shall limit Process Throughput <= 30.0 gallons per hour 12-hour average (calculated on a twelve-hour block average) of distillate oil (#1 or #2). [Minn. R. 7007.0800, subps. 4-5, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.13.16 The Administrator will not consider periods of excess emissions to be indicative of a violation provided that the percent of the total number of possible contiguous periods of excess emissions in a quarter (excluding periods of startup, shutdown, or malfunction and periods when the facility is not operating) during which excess emissions occur does not exceed: 1) One percent for TRS emissions from recovery furnaces; or 2) Six percent for average opacities from recovery furnaces. [40 CFR 60.284, Minn. R. 7011.2450]

5.13.17 Recordkeeping: The Permittee shall record and maintain records of the black liquor solids firing rate in units of ton/day on a daily basis. [40 CFR 63.866(c)(1), Minn. R. 7007.0800, subp. 5, Minn. R. 7011.7700]

5.13.18 Reporting: The Permittee shall notify the Administrator before the black liquor solids firing rate for any kraft or soda recovery furnace during any 24-hour averaging period is increased by more than 10 percent above the level measured during the most recent performance test. [40 CFR 63.867(b)(3)(iv), Minn. R. 7011.7700]

5.13.19 Monthly Recordkeeping -- Sulfur Dioxide and Carbon Monoxide Emissions. By the 15th of the month, the Permittee shall calculate and record the following: 1) The total SO2 and CO emissions for the previous calendar month 2) The 12-month rolling sum of SO2 and CO emissions for the previous 12-month period by summing the monthly emissions data for the previous 12 months. [Minn. R. 7007.0800, subps. 4-5]

5.13.20 The Permittee shall record total distillate oil usage in gallons once every 12 hours. [Minn. R. 7007.0800, subps. 4-5, Title I Condition: 40 CFR 52.21(j)(BACT) &


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation Minn. R. 7007.3000]

5.13.21 The Permittee shall record and calculate every 12 hours the 12 hour block average of distillate process throughput, in gallons/hour, of distillate oil that was burned in the recovery furnace to verify that the distillate process throughput was less than or equal to 30.0 gallons/hour using a 12-hour Block Average. The Permittee shall maintain these records for a period of 5 years.. [Minn. R. 7007.0800, subps. 4-5, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.13.22 Fuel Supplier Documentation: The Permittee shall obtain and maintain fuel supplier documentation for each shipment of fuel distillate oil (#1 and #2), documenting that the sulfur content does not exceed 0.050% by weight. Records shall be maintained for 5 years. [Minn. R. 7007.0800, subps. 4-5, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.13.23 Emissions Monitoring: The Permittee shall use a COMS to measure Opacity emissions from EQUI 9. [40 CFR 63.865(c)(1), 40 CFR pt. 64, Minn. R. 7017.1006, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.13.24 ESP Monitoring: The COMS for EQUI 9 shall be used to assess proper operation of this ESP (TREA 1). [40 CFR 63.865(c)(1), 40 CFR 64.7(a), Minn. R. 7007.0800, subp. 2]

5.13.25 SSM Excess Emissions Report: Report any/all excess emissions quarterly within 30 days following the end of the calendar quarterly. The report must contain the required elements specified in 40 CFR Section 63.10(c). Reporting excess emissions below the violation thresholds of 63.864(k) does not constitute a violation of the Subpart MM standard. When no excess emissions have occurred, the Permittee shall submit a semi-annual report stating that no excess emissions have occurred during the reporting period. Subpart MM excess emission reports may be combined with Subpart S semi-annual excess emission reports. [40 CFR 63.867(c), Minn. R. 7011.7700]

5.13.26 On-going compliance provisions. Recovery Furnace units are required to implement corrective action if the monitoring exceedances, when the average of ten consecutive 6-minute averages result in a measurement greater than 20 percent opacity. [40 CFR 63.864(k)(1)(i), Minn. R. 7011.7700]

5.13.27 The Recovery Furnace is in violation of the standards of 63.862 if the opacity is greater than 35 percent for 6 percent or more of the operating time within any quarterly period. [40 CFR 63.864(k)(2)(i), Minn. R. 7011.7700]

5.13.28 The Permittee shall install, calibrate, maintain and


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation operate a continuous monitoring system for measuring and recording, Nitrogen Oxide emissions, Carbon Monoxide emissions, Total Reduced Sulfur emissions, and either Oxygen or Carbon Dioxide. (Monitoring associated with Title I emission limit). [40 CFR 60.45(a), 40 CFR 64.7(a), Minn. R. 7017.1006, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(o)(visibility) & Minn. R. 7007.3000]

5.13.29 Alternative Biomass Fuel Testing Authorization: The Permittee is authorized to conduct operational test burns of the following biomass fuels: BLS Soap Tall Oil, Wastewater Treatment Residual, Glycerin or glycerol, herbs, nuts; vegetable oils; crop field residue or field processing residues; shells, husks, seeds, dust, screenings and other agricultural processing residues; cultivated grasses or grass by products and leaves. Acceptable biomass fuels do not include wood that has been painted or pressure treated; peat; off-site generated waste oil, farm chemicals, pesticide containers, demolition waste except wood, waste from farms from an open dump, tire derived fuels, non-agricultural industrial process wastes except wood derived wastes or any material meeting the definition of a hazardous waste. [Minn. R. 7007.0800, subp. 2]

5.13.30 Alternative Biomass Fuel Testing Requirements and Restrictions: Operational test burn will include, but not be limited to, nitrogen oxide, carbon monoxide, and opacity emission limits monitored by existing CEMs and COMs. Alternative biomass fuels will further be limited to less than 5,000 tons. Alternative test fuels will be limited to less than 25 percent of the heat input capacity of the boiler. Feasibility test burns will be monitored for NOx, CO, TRS, and opacity. If feasibility test burns prove successful, then PM, PM10, PM2.5, SO2 and VOC performance test data will be gathered during the performance testing phase. Preliminary fuel testing will be completed to estimate the maximum HAP emissions (HCl and Hg). [Minn. R. 7007.0800, subp. 2]

5.13.31 Test burns shall consist of up to two phases - feasibility and performance testing. If an alternative biomass fuel meets feasibility requirements (as defined by the Permittee) such that it may be proposed as an additional fuel, the Permittee may move into the performance testing phase. [Minn. R. 7007.0800, subp. 2]

5.13.32 Alternative Biomass Fuel Testing Restrictions: Feasibility test burns for any alternative biomass fuel shall be limited to no more than 168 hours of operation using the fuel, and a test period not to exceed 30 days.


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation Performance tests for any alternative biomass fuel shall be limited to no more than 168 additional hours of operation using the proposed fuel and a test period not to exceed 60 additional days. [Minn. R. 7007.0800, subp. 2]

5.13.33 Performance Test Plan: The permittee shall submit a performance test plan : Due 30 calendar days before Performance Test Date (Alternative Biomass Fuel Emission Testing submittal) of the operational and emission testing of a biomass fuel (emission testing will be conducted only if operational testing has been proven feasible), the permitee shall submit a written performance test notification and test plan. The test plan shall include (1) the type(s) and estimated amount of biomass to be tested, (2) operating parameters and anticipated fuel mixes during the emission testing of the boiler to be tested, (3) air pollutants that will be monitored (ie., PM, PM-10, and VOC), and (4) a testing schedule. [Minn. R. 7017.2018, Minn. R. 7017.2030, subps. 1-4]

5.13.34 Alternative Biomass Fuel Emission Testing Notification and submittals; Pretest meeting: due 7 days before Performance Test Test Report: Due 45 days after Performance Test Test Report: CD copy due 105 days after Performance Test The Notification, the test Plan, and Test Report may be submitted in alternative format as allowed by Minn. R. 7017.2018. [Minn. R. 7017.2018, Minn. R. 7017.2030, subps. 1-4, Minn. R. 7017.2035, subps. 1-2]

EQUI 12 EU902 Paint Spray

Booth - Spray Booth/Coating Line

5.14.1 Particulate Matter <= 0.30 grains per dry standard cubic foot of exhaust gas unless required to further reduce emissions to comply with the less stringent limit of either Minn. R. 7011.0730 or Minn. R. 7011.0735. [Minn. R. 7011.0715, subp. 1(A)]


5.14.3 Operating Hours <= 1044 hours per year 12-month rolling sum. [Title I Condition: Avoid major modification under 40 CFR 52.21(b)(2) & Minn. R. 7007.3000]

5.14.4 Spray Booth Operation: The particulate filter for EQUI 12 shall be securely in place whenever paint spraying occurs. The filter shall be maintained and replaced according to manufacturer's specifications. [Title I Condition: Avoid major modification under 40 CFR


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation 52.21(b)(2) and Minn. R. 7007.3000]

5.14.5 Monthly Recordkeeping -- spray booth operating hours By the 15th of the month, the Permittee shall calculate and record the following: 1) The total spray booth hours of operation for the previous calendar month 2) The 12-month rolling sum of spray booth hours of operation for the previous 12-month period by summing the monthly emissions data for the previous 12 months. [Minn. R. 7007.0800, subps. 4-5, Title I Condition: Avoid major source under 40 CFR 52.21(b)(2) & Minn. R. 7007.3000]

EQUI 13 EU340 Lime Kiln - Kiln 5.15.1 The Permittee shall limit emissions of Particulate Matter

<= 12.7 pounds per hour 3-hour average, as determined by performance test. This is based on an EPA approved limit from a letter dated September 29, 2008. [Title I Condition: 40 CFR 52.21(b)(2)(i)(netting) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

5.15.2 The Permittee shall limit emissions of Particulate Matter <= 0.066 grains per dry standard cubic foot 3-hour average, as determined by performance test, @10% oxygen. This is the NSPS 40 CFR pt. 60, subp. BB limit. The NESHAP 40 CFR pt. 63, subp. MM limit is 0.064 gr/dscf, however, the EPA approved the alternative limit in a letter dated September 29, 2008. [40 CFR 60.282(a)(3)(i), 40 CFR 63.862(a)(ii), Minn. R. 7011.2450, Minn. R. 7011.7700]

5.15.3 The Permittee shall limit emissions of PM < 10 micron <= 12.7 pounds per hour 3-hour average, as determined by performance test. This is based on an EPA approved limit from a letter dated September 29, 2008. [Title I Condition: 40 CFR 52.21(b)(2)(i)(netting) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

5.15.4 The Permittee shall limit emissions of Sulfur Dioxide <= 13.5 pounds per hour 3-hour average, as determined by performance test. [Title I Condition: 40 CFR 52.21(b)(2)(i)(netting) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

5.15.5 The Permittee shall limit emissions of Nitrogen Oxides <= 34.9 pounds per hour 3-hour average, as determined by performance test. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000, Title I Condition:


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

5.15.6 The Permittee shall limit emissions of Carbon Monoxide <= 23.7 pounds per hour 3-hour average, as determined by performance test. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(modeling)]

5.15.7 The Permittee shall limit emissions of Volatile Organic Compounds <= 11.4 pounds per hour 3-hour average, as determined by performance test, measured as Carbon excluding methane. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.15.8 The Permittee shall limit emissions of Sulfur - Total Reduced including H2S <= 8.0 parts per million 12-hour average, calculated on a dry basis and corrected to 10% oxygen. This is the limit for both BACT and NSPS 40 CFR pt. 60, subp. BB. [40 CFR 60.283(a)(5), Minn. R. 7011.2045, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.15.9 The Permittee shall limit Production <= 237 tons per day of lime, calculated on a twelve-hour block average, unless a new limit is set pursuant to Minn. R. 7017.2025, subp. 3, based on the most recent MPCA approved performance test where compliance was demonstrated. The twelve-hour block average shall be calculated by dividing the total weight by the total operating time in each twelve-hour block. Down time of 15 or more minutes is not to be included as operating time. [Minn. R. 7017.2025, subp. 3, Minn. R. 7017.2025, subp. 3a]

5.15.10 Fuel Usage: Limited to natural gas. Low Volume High Concentration (LVHC) Non-condensable gas (NCG) is also oxidized in the lime kiln. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.15.11 The Permittee shall calibrate, maintain and operate a continuous monitoring system for measuring and recording the concentration of Total Reduced Sulfur emissions on a dry basis and the percent of oxygen by volume on a dry basis. [40 CFR 60.284, 40 CFR 64.7(a), Minn. R. 7017.1006, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.15.12 The Permittee shall maintain records of parameter monitoring data required under 40 CFR Section 63.864, including any period when the operating parameter levels were inconsistent with the levels established during the initial performance test, with a brief explanation of the cause of the deviation, the time the


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation deviation occurred, the time corrective action was initiated and completed, and the corrective action taken. [40 CFR 63.866(c)(3), Minn. R. 7011.7700]

5.15.13 Recordkeeping: The Permittee shall record the production rate of CaO (calcium oxide or lime) in units of tons/day and maintain the records. [40 CFR 63.866(c)(2), Minn. R. 7011.7700]

5.15.14 Monthly Recordkeeping -- lime production By the 15th of the month, the Permittee shall calculate and record the amount of lime produced for the previous calendar month. [Minn. R. 7007.0800, subp. 6]

5.15.15 NOx Emissions Calculation: The Permittee shall calculate NOx emissions on a semi-annual basis. The NOx emission factor shall be obtained from the most recent MPCA approved performance test. The NOx emissions shall be calculated and converted to a tons/day basis for determining the total NOx emissions from the Facility and comparison to the NOx emissions cap (COMG 5). Lime Kiln NOx emissions (tons/day) = (MM lbs BLS/day * 1,000,000/MM * ton/2000 lbs) * (0.21 lbs/ton of BLS * ton/2000 lbs) Note that 0.21 lbs NOx/ton of BLS produced is the relationship established during the 2012 performance test. The next performance test for NOx is scheduled to be completed before 9/5/2017. [Minn. R. 7007.0800, subp. 6, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(o)(visibility) & Minn. R. 7007.3000]

EQUI 15 EU420 Boiler #1 -

Boiler

5.16.1 The Permittee shall limit emissions of Particulate Matter <= 0.60 pounds per million Btu heat input 3-hour average, as determined by performance test. The potential to emit from the unit is 0.008 lb/MMBtu. [Minn. R. 7011.0510, subp. 1, Title I Condition: 40 CFR 52.21(b)(2)(i)(netting) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

5.16.2 The Permittee shall limit emissions of PM < 10 micron <= 0.60 pounds per million Btu heat input 3-hour average, as determined by performance test. The potential to emit from the unit is 0.008 lb/MMBtu. [Title I Condition: 40 CFR 52.21(b)(2)(i)(netting) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

5.16.3 The Permittee shall limit Opacity <= 20 percent opacity,


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation except for one six-minute period per hour of not more than 60 percent Opacity. [Minn. R. 7011.0510, subp. 2]

5.16.4 The Permittee shall limit emissions of Nitrogen Oxides <= 0.20 pounds per million Btu heat input 30-day rolling average. [Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

5.16.5 Fuel burned: limited to natural gas. Exhaust from the sludge dryer (EQUI 24) may also vent to boiler #1. Non-condensable gas (NCG) is also oxidized in boiler #1. The amount of NCG burned in boiler #1 is limited under COMG 6. [Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(j)(BACT), Title I Condition: 40 CFR 52.21(k)(modeling)]

5.16.6 The Permittee shall calibrate, maintain and operate a continuous monitoring system for measuring and recording the Nitrogen Oxide emissions, and either Oxygen or Carbon Dioxide. [Minn. R. 7017.1006]

5.16.7 The affected source of 40 CFR pt. 63, subp. DDDDD is the collection at a major source of all existing industrial, commercial, and institutional boilers and process heaters within a subcategory as defined in 40 CFR Section 63.7575. This unit is part of the subcategory "units designed to burn gas 1 fuels." [40 CFR 63.7490]


Boiler

5.17.1 The Permittee shall limit emissions of Particulate Matter <= 13.0 pounds per hour 3-hour average, as determined by performance test. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.17.2 The Permittee shall limit emissions of PM < 10 micron <= 11.7 pounds per hour 3-hour average, as determined by performance test. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.17.3 The Permittee shall limit emissions of Front-half Particulate Matter <= 0.037 pounds per million Btu heat input 3-hour average, as determined by performance test. (Filterable PM - NESHAP limit). [40 CFR 63.7500(a)(1), 40 CFR pt. 63, subp. DDDDD(Table 2), Minn. R. 7011.7050]

5.17.4 The Permittee shall limit Opacity <= 10 percent opacity 24-hour block average (NESHAP limit). [40 CFR 63.7500(a)(2), 40 CFR pt. 63, subp. DDDDD(Table 4), Minn. R. 7011.7050]

5.17.5 The Permittee shall limit emissions of Sulfur Dioxide <= 39.5 pounds per hour using 6-hour rolling average. This limit does not apply when NCG is being oxidized in Boiler #2. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000, Title I Condition: 40 CFR


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation 52.21(k)(modeling) & MInn. R. 1007.3000]

5.17.6 The Permittee shall limit emissions of Sulfur Dioxide <= 9.4 pounds per hour 12-month rolling average. This limit does not apply when NCG is being oxidized in Boiler #2. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.17.7 The Permittee shall limit emissions of Nitrogen Oxides <= 100.2 pounds per hour 30-day rolling average. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.17.8 The Permittee shall limit emissions of Carbon Monoxide <= 800 pounds per hour 1-hour average. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(modeling)]

5.17.9 The Permittee shall limit emissions of Carbon Monoxide <= 200 pounds per hour 12-month rolling average. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(modeling) & MInn. R. 7007.3000]

5.17.10 The Permittee shall limit emissions of Carbon Monoxide <= 720 parts per million 30-day rolling average, calculated by volume on a dry basis @ 3% oxygen. (NESHAP limit). [40 CFR 63.7500(a)(1), 40 CFR pt. 63, subp. DDDDD(Table 2), Minn. R. 7011.7050]

5.17.11 The Permittee shall limit emissions of Volatile Organic Compounds <= 40.2 pounds per hour 3-hour average, as determined by performance test, as determined by performance test, measured as C excluding methane. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.17.12 The Permittee shall limit emissions of Hydrochloric acid <= 0.022 pounds per million Btu heat input 3-hour average, as determined by performance test. [40 CFR 63.7500(a)(1), 40 CFR pt. 63, subp. DDDDD(Table 2), Minn. R. 7011.7050]

5.17.13 The Permittee shall limit emissions of Mercury <= 5.7E-06 pounds per million Btu heat input 3-hour average, as determined by performance test. [40 CFR 63.7500(a)(1), 40 CFR pt. 63, subp. DDDDD(Table 2), Minn. R. 7011.7050]

5.17.14 Fuel Burned: Fuels to be burned are limited to bark, wood refuse, wastewater treatment sludge, paper, and natural gas. Non-condensable gas (NCG) is also oxidized in Boiler #2. The amount of NCG burned in Boiler #2 is limited under COMG 6. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000, Title I Condition: 40 CFR pt. 52, 21(k)(modeling) & Minn. R. 7007.3000]

5.17.15 Fuel Usage <= 27010 tons per month 12-month rolling average. The fuel usage limit is for combined total of bark, wood refuse, paper, and sludge and shall be expressed in units of green tons per month. [Title I


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation Condition: 40 CFR 52.21(o)(visibility) & Minn. R. 7007.3000]

5.17.16 Fuel Usage <= 5193 tons per month 12-month rolling average (SLUDGE USAGE LIMIT). [Title I Condition: 40 CFR 52.21(o)(visibility) & Minn. R. 7007.3000]

5.17.17 Monthly Recordkeeping: By the 15th of the month, the Permittee shall calculate and record the 12-month rolling average for the previous 12-month period by calculating the average monthly fuel usage for the previous 12 months for: 1) combined fuel usage (bark, wood refuse, paper, and sludge) 2) sludge usage. [Minn. R. 7007.0800, subp. 5]

5.17.18 Fuel Usage <= 39.7 tons per hour of total bark, wood refuse, paper, and sludge, calculated on a six-hour block average. This limit is in effect unless a new limit is set pursuant to Minn. R. 7017.2025, subp. 3, based on the most recent MPCA approved performance test where compliance was demonstrated. The six-hour block average shall be calculated by dividing the total weight by the total operating time in each six-hour block. Down time of 15 or more minutes is not to be included as operating time. [Minn. R. 7017.2025, subp. 3]

5.17.19 Daily Recordkeeping. On each day of operation, the Permittee shall calculate, record, and maintain a record of the combined fuel usage (bark, wood refuse, paper, and sludge). This is for the tons/hour fuel usage limit, calculated on a six-hour block average basis. [Minn. R. 7007.0800, subp. 5]

5.17.20 ESP Monitoring: The Permittee shall use the COMS (EQUI 80) to assess proper operation of the ESP (TREA 5). [40 CFR 64.7(a), Minn. R. 7007.0800, subp. 2]

5.17.21 Emissions Monitoring: The Permittee shall use a COMS to measure Opacity emissions from EQUI 16. [40 CFR 63.7525(c), 40 CFR 64.7(a), Minn. R. 7017.1006, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.17.22 The Permittee shall calibrate, maintain, and operate a continuous monitoring system for measuring and recording Nitrogen Oxide, Sulfur Dioxide, and Carbon Monoxide emissions. [40 CFR 64.7(a), Minn. R. 7017.1006, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.17.23 Emissions Monitoring: The owner or operator shall use a Carbon Monoxide CEMS to measure Carbon Monoxide emissions from EQUI 16 . Additional monitoring requirements are also located at EQUI 90. [40 CFR 63.7525(a), Minn. R. 7017.1006]

5.17.24 Alternative Biomass Fuel Testing Authorization: The


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation Permittee is authorized to conduct operational test burns of the following biomass fuels: BLS Soap, BLS Soap Tall Oil, Wastewater Treatment Residual, Glycerin or glycerol, herbs, nuts; vegetable oils; crop field residue or field processing residues; shells, husks, seeds, dust, screenings and other agricultural processing residues; cultivated grasses or grass by products and leaves. Acceptable biomass fuels do not include wood that has been painted or pressure treated; peat; off-site generated waste oil, farm chemicals, pesticide containers, demolition waste except wood, waste from farms from an open dump, tire derived fuels, non-agricultural industrial process wastes except wood derived wastes or any material meeting the definition of a hazardous waste. [Minn. R. 7007.0800, subp. 2]

5.17.25 Alternative Biomass Fuel Testing Requirements and Restrictions: Operational test burn will include, but not be limited to, nitrogen oxide, sulfur dioxide, carbon monoxide, and opacity emission limits monitored by existing CEMs and COMs. Alternative biomass fuels will further be limited to less than 5,000 tons and no more than 7 days (or 168 hours) operation using the fuel, and a testing period to last no more than 30 operational days beginning the first day fuel is used. Further alternative test fuels will be limited to less than 25 percent of the heat input capacity of the boiler (i.e., less than 25% of 395 mmBTU/hr or 99 mmBTU/hr). Operational test burns will be monitored for NOx, CO, SO2, and opacity. If operational test burns prove successful, then PM, PM-10 and VOC performance test data will be gathered during the test. Preliminary fuel testing will be completed to estimate the maximum HAP emissions (HCl and Hg). [Minn. R. 7007.0800, subp. 2]

5.17.26 Test burns shall consist of up to two phases - feasibility and performance testing. If an alternative biomass fuel meets feasibility requirements (as defined by the Permittee) such that it may be proposed as an additional fuel, the Permittee may move into the performance testing phase. [Minn. R. 7007.0800, subp. 2]

5.17.27 Alternative Biomass Fuel Testing Restrictions: Feasibility test burns for any alternative biomass fuel shall be limited to no more than 168 hours of operation using the fuel, and a test period not to exceed 30 days. Performance tests for any alternative biomass fuel shall be limited to no more than 168 additional hours of operation using the proposed fuel and a test period not to exceed 60 additional days. [Minn. R. 7007.0800, subp. 2]

5.17.28 Alternative Biomass Fuel Emission Testing Notification


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation and submittals; Pretest meeting: due 7 days before Performance Test Test Report: Due 45 days after Performance Test Test Report: CD copy due 105 days after Performance Test The Notification, the test Plan, and Test Report may be submitted in alternative format as allowed by Minn. R. 7017.2018. [Minn. R. 7017.2018, Minn. R. 7017.2030, subps. 1-4, Minn. R. 7017.2035, subps. 1-2]

5.17.29 NESHAP REQUIREMENTS The affected source of 40 CFR pt. 63, subp. DDDDD is the collection at a major source of all existing industrial, commercial, and institutional boilers and process heaters within a subcategory as defined in 40 CFR Section 63.7575. This unit is part of the subcategory "Stoker/sloped grate/other unit designed to burn wet biomass.". [40 CFR 63.7490, Minn. R. 7011.7050]

5.17.30 Fuel Analysis. The Permittee must keep records of the type and amount of all fuels burned in each boiler or process heater during the reporting period to demonstrate that all fuel types and mixtures of fuels burned would result in equal to or lower fuel input of chlorine, mercury, and TSM than the maximum values calculated during the last performance test, if you demonstrate compliance through performance testing. [40 CFR 63.7540(a)(2), Minn. R. 7011.7050]

5.17.31 To demonstrate continuous compliance with the CO emission limit, the Permittee must meet the requirements below. - Continuously monitor CO according to 40 CFR Sections 63.7525(a) and 63.7535. - Maintain a CO emission level below or at the CO emission limit at all times the affected unit is operating. - Keep records of CO levels according to 40 CFR Section 63.7555(b). - Record and make available upon request results of CO CEMS performance audits, dates and duration of periods when the CO CEMS is out of control to completion of the corrective actions necessary to return the CO CEMS to operation consistent with the Site-Specific Monitoring Plan. [40 CFR 63.7540(a)(8), Minn. R. 7011.7050]

5.17.32 The Permittee must be in compliance with the emission limits, work practice standards, and operating limits in 40 CFR pt. 63, subp. DDDDD. These limits apply at all times the affected unit is operating, except during periods of startup and shutdown. [40 CFR 63.7505(a), Minn. R. 7011.7050]

5.17.33 Startup & Shutdown. For startup and shutdown, the Permittee must meet the work practice standards


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation according to 40 CFR pt. 63, subp. DDDDD, Table 3, Items 5 and 6. [40 CFR 63.7540(d), Minn. R. 7011.7050]

5.17.34 The Permittee must maintain records of the calendar date, time, occurrence and duration of each startup and shutdown. [40 CFR 63.7555(i)]

5.17.35 The Permittee must maintain records of the type(s) and amount(s) of fuels used during each startup and shutdown. [40 CFR 63.7555(j)]

5.17.36 Boiler Load. The Permittee must maintain the operating load of each unit such that it does not exceed 110 percent of the highest hourly average operating load recorded during the most recent performance test. [40 CFR 63.7500(a)(2), 40 CFR pt. 63, subp. DDDDD(Table 4), Minn. R. 7011.7050]

5.17.37 The Permittee must demonstrate compliance with all applicable emission limits using performance stack testing, fuel analysis, or CMS, including a CEMS, COMS, CPMS, or PM CPMS, where applicable. The Permittee may demonstrate compliance with the applicable emission limit for HCl, mercury, or TSM using fuel analysis if the emission rate calculated according to 40 CFR Section 63.7530(c) is less than the applicable emission limit. (For gaseous fuels, the Permittee may not use fuel analyses to comply with the TSM alternative standard or the HCl standard.) Otherwise, the Permittee must demonstrate compliance for HCl, mercury, or TSM using performance testing, if subject to an applicable emission limit listed in 40 CFR pt. 63, subp. DDDDD, Table 2. [40 CFR 63.7505(c), Minn. R. 7011.7050]

5.17.38 The Permittee must comply with all applicable requirements of 40 CFR pt. 63, subp A, as follows: 63.6(h)(2), 63.6(h)(4-9), 63.7(b), 63.7(c)(2-3), 63.7(d), 63.7(e)(2-3), 63.7(g), and 63.7(h). A copy of 40 CFR pt. 63, subp. A is included in Appendix J. If the standard changes or 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. [40 CFR 63.7565, 40 CFR pt. 63, subp. A, Minn. R. 7007.0400, subp. 3, Minn. R. 7007.1150-7007.1500, Minn. R. 7011.7000]


Boiler

5.18.1 The Permittee shall limit emissions of Nitrogen Oxides <= 0.050 pounds per million Btu heat input 30-day


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation rolling average. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

5.18.2 The Permittee shall limit emissions of Nitrogen Oxides <= 0.20 pounds per million Btu heat input 30-day rolling average. This standard applies at all times including periods of startup, shutdown, or malfunction. [40 CFR 60.44b(a), Minn. R. 7011.0565]

5.18.3 The Permittee shall limit emissions of Carbon Monoxide <= 0.090 pounds per million Btu heat input 3-hour average, as determined by performance test. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.18.4 The Permittee shall limit emissions of Carbon Monoxide <= 33.6 pounds per hour 3-hour average, as determined by performance test. [Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

5.18.5 The Permittee shall limit emissions of Volatile Organic Compounds <= 0.0090 pounds per million Btu heat input 3-hour average, as determined by performance test, measured as Carbon excluding methane (this is equivalent to 3.4 lb/hr). [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.18.6 Fuel Burned: Fuel to be burned is limited to natural gas. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

5.18.7 Annual Capacity Factor: The Permittee shall record and maintain records of the amount of fuel combusted each day and calculate the annual capacity factor for natural gas for the reporting period. The annual capacity factor is determined on a 12-month rolling average basis with a new annual capacity factor calculated at the end of each calendar month. [40 CFR 60.49b(d)(1), Minn. R. 7011.0565]

5.18.8 The Permittee shall calibrate, maintain, and operate CEMS for measuring NOx and O2 (or CO2) emissions discharged to the atmosphere, and shall record the output of the system. [40 CFR 60.48b(b)(1), Minn. R. 7011.0565, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

5.18.9 The CEMS shall be operated and data recorded during all periods of operation of EQUI 17 except for CEMS breakdowns and repairs. Data is recorded during calibration checks, and zero and span adjustments. [40 CFR 60.48b(c), Minn. R. 7011.0565]

5.18.10 The 1-hour average NOx emission rates measured by the NOx CEMS shall be expressed in lb/MMBtu heat input and shall be used to calculate the 30-day average emission rate. The 1-hour averages shall be calculated


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation using data points required under 40 CFR Section 60.13(h)(2). [40 CFR 60.48b(d), Minn. R. 7011.0565]

5.18.11 When NOx emissions data are not obtained because of CEMS breakdowns, repairs, calibration checks, and zero and span adjustments, emission data will be obtained by using standby monitoring systems, Method 7 or 7A of Appendix A of 40 CFR pt. 60, or other approved reference methods to provide emission data for a minimum of 75 percent of the operating hours of EQUI 17, in at least 22 out of 30 successive EQUI 17 operating days. [40 CFR 60.48b(f), Minn. R. 7011.0565]

5.18.12 The affected source of 40 CFR pt. 63, subp. DDDDD is the collection at a major source of all existing industrial, commercial, and institutional boilers and process heaters within a subcategory as defined in 40 CFR Section 63.7575. This unit is part of the subcategory "units designed to burn gas 1 fuels". [40 CFR 63.7490, Minn. R. 7011.7050]


Boiler

5.19.1 The Permittee shall limit emissions of Nitrogen Oxides <= 0.050 pounds per million Btu heat input 30-day rolling average. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

5.19.2 The Permittee shall limit emissions of Nitrogen Oxides <= 0.20 pounds per million Btu heat input 30-day rolling average. [40 CFR 60.44b(a), Minn. R. 7011.0565]

5.19.3 The Permittee shall limit emissions of Carbon Monoxide <= 0.090 pounds per million Btu heat input 3-hour average, as determined by performance test. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.19.4 The Permittee shall limit emissions of Carbon Monoxide <= 33.6 pounds per hour 3-hour average, as determined by performance test. [Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

5.19.5 The Permittee shall limit emissions of Volatile Organic Compounds <= 0.0090 pounds per million Btu heat input 3-hour average, as determined by performance test, measured as C excluding methane (this is equivalent to 3.4 lb/hr). [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.19.6 Fuel Burned: Fuel to be burned is limited to natural gas. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

5.19.7 Annual Capacity Factor: Record and maintain records of the amounts of each fuel combusted during each day


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation and calculate the annual capacity factor for natural gas each calendar quarter. The annual capacity factor is determined on a 12-month rolling average basis with a new annual capacity factor calculated at the end of each calendar month. [40 CFR 60.49b(d), Minn. R. 7011.0565]

5.19.8 The Permittee shall calibrate, maintain, and operate a continuous monitoring system for measuring and recording Nitrogen Oxide emissions. [40 CFR 60.45(a), Minn. R. 7017.1006, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000, Title I Condition: 40 CFR pt. 52, 21(k)(modeling) & Minn. R. 7007.3000]

5.19.9 Records of Startup, Shutdown, or Malfunction: Any owner or operator subject to the provisions of this part 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]

5.19.10 The affected source of 40 CFR pt. 63, subp. DDDDD is the collection at a major source of all existing industrial, commercial, and institutional boilers and process heaters within a subcategory as defined in 40 CFR Section 63.7575. This unit is part of the subcategory "units designed to burn gas 1 fuels". [40 CFR 63.7490, Minn. R. 7011.7050]

EQUI 19 EU505 No. 2 Paper



5.20.2 Opacity <= 20 percent opacity except for one six-minute per hour of not more than 60 percent opacity. [Minn. R. 7011.0710, subp. 1(B)]

5.20.3 Periodic Monitoring: the Permittee shall perform proper maintenance of the paper machines so as to prevent excessive amounts of particulate matter from being emitted from the associated stack/vents. [Minn. R. 7007.0800, subp. 4]


Machine - Other Emission


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation Unit


5.21.2 Opacity <= 20 percent opacity except for one six-minute per hour of not more than 60 percent opacity. [Minn. R. 7011.0710, subp. 1(B)]




5.22.1 Particulate Matter <= 0.30 grains per dry standard cubic foot of exhaust gas unless required to further reduce emissions to comply with the less stringent limit of either Minn. R. 7011.0730 or Minn. R. 7011.0735. [Minn. R. 7011.0610, subp. 1(A)(1)]

5.22.2 Opacity <= 20 percent opacity except for one six-minute period per hour of not more than 60 percent opacity. [Minn. R. 7011.0610, subp. 1(A)(2)]

5.22.3 Fuel to be burned is limited to natural gas. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000, Title I Condition: 40 CFR pt. 52, 21(k)(modeling) & Minn. R. 7007.3000]






5.23.3 Periodic Monitoring: the Permittee shall perform proper


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation maintenance of the paper machines so as to prevent excessive amounts of particulate matter from being emitted from the associated stack/vents. [Minn. R. 7007.0800, subp. 4]

EQUI 24 EU903 Sludge Dryer -

Other Emission Unit



5.24.3 Operation and Maintenance Plan: The plan shall identify corrective action procedures to be followed to return the control equipment to within specified range(s); corrective action procedures to be followed in the event of a malfunction, breakdown or exceedance of operating ranges; a description of inspection procedures to be followed; and records kept to demonstrate plan implementation. [Minn. R. 7007.0800, subp. 2]

5.24.4 Control Equipment Monitoring: Observe and record once per operating day, the liquid flow rate and pressure drop for TREA 25 and TREA 26. [Minn. R. 7007.0800, subp. 14]

5.24.5 The Permittee shall operate and maintain the control equipment (TREA 25 and TREA 26) at all times that stack gas from the control equipment is vented directly to the atmosphere. The Permittee shall document periods of operation of the control equipment and the periods that the bypass valve (213-ZS-062) directs stack gas from the control equipment to the atmosphere rather than directing the stack gas for combustion in Boliers #1 and #2 (EQUIs 15 and 16). [Minn. R. 7007.0800, subp. 14, Minn. R. 7007.0800, subp. 2]

5.24.6 TREA 25 (this requirement applies when the facility is not burning stack gas in Boilers #1 or #2): Liquid Flow Rate >= 70 gallons per minute 3-hour block average. To calculate the average flow rate, divide total flow by total operating time in each three hour-block. Down time of 15 or more minutes is not to be included as operating time. Readings taken by continuous monitor at one minute increments. [Minn. R. 7017.2025, subp. 3]

5.24.7 TREA 25 (this requirement applies when the facility is not burning stack gas in Boilers #1 or #2): Pressure Drop >= 2.0 inches of water column 3-hour block


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation average or as determined during the most recent performance test. Three-hour block average is the average scrubber pressure drop in each three-hour block. Downtime of 15 or more minutes is not to be included as operating time. [Minn. R. 7017.2025, subp. 3]

5.24.8 TREA 26 (this requirement applies when the facility is not burning stack gas in Boilers #1 or #2): Liquid Flow Rate >= 788 gallons per minute 3-hour block average. To calculate the average flow rate, divide total flow by total operating time in each three hour-block. Down time of 15 or more minutes is not to be included as operating time. Readings taken by continuous monitor at one minute increments. [Minn. R. 7017.2025, subp. 3]

5.24.9 TREA 26 (this requirement applies when the facility is not burning stack gas in Boilers #1 or #2): Pressure Drop >= 0.5 inches of water column 3-hour block average or as determined during the most recent performance test. Three-hour block average is the average scrubber pressure drop in each three-hour block. Downtime of 15 or more minutes is not to be included as operating time. [Minn. R. 7017.2025, subp. 3]

EQUI 25 EU909 Off-Machine

Coater - Other Emission Unit

5.25.1 HAPs - Organic <= 20 percent of the mass of coating solids applied for each calendar month for the web coating line (as defined in 40 CFR Section 63.3310). [40 CFR 63.3320(b)(3), Minn. R. 7011.7385]

5.25.2 The Permittee shall maintain the following records on a monthly basis: Records specified in 40 CFR Section 63.10(b)(2) of all measurements need to demonstrate compliance, including: volatile matter and coating solids content data for the purpose of demonstrating compliance in accordance with the requirements of 40 CFR Section 63.3360(d); material usage, organic HAP usage, volatile matter usage, and coating solids usage and compliance demonstrations using these data in accordance with 40 CFR Section 63.3370(c). [40 CFR 63.10(b)(1), 40 CFR 63.3410(a), Minn. R. 7011.7385]

5.25.3 The monthly average of all coating materials used at an existing affected source does not exceed 0.2 kg organic HAP per kg coating solids as-applied on a monthly average basis using equation 5 of Section 63.3370 as specified in the following requirements. [40 CFR 63.3370(a)(2)(iv), 40 CFR 63.3370(c)(5)(ii), Minn. R.



5.25.4 The Permittee must determine the organic HAP applied on these web coating lines using Equation 5 of Appendix C of this permit. The organic HAP emitted from an uncontrolled web coating line is equal to the organic HAP applied on that web coating line. [40 CFR 63.3370(c)(4), Minn. R. 7011.7385]

5.25.5 By the end of each calendar month, the Permittee shall calculate the following for the previous calendar month: 1) The total organic HAP emitted by summing the HAP emissions calculated for all units subject to 40 CFR pt. 63, subp. JJJJ as detailed earlier in this permit; 2) The coating solids content of each coating material applied during the month following the procedure detailed earlier in this permit; and 3) The total organic HAP emission rate based on coating solids applied using Equation 5 of Appendix C of this permit. [40 CFR 63.3370(c)(4), Minn. R. 7011.7385]

5.25.6 The Permittee must comply with all applicable requirements of 40 CFR pt. 63, subp A, as follows: 63.4(b), 63.5(b)(4), 63.5(b)(6), 63.6(e)(1)(i-ii), 63.6(f)(2-3), 63.9(h), 63.9(j), 63.10(a), 63.10(b)(1), 63.10(d)(1), and 63.10(d)(4). A copy of 40 CFR pt. 63, subp. A is included in Appendix J. If the standard changes or 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. [40 CFR pt. 63, subp. A, 40 CFR pt. 63, subp. JJJJ, Minn. R. 7007.0400, subp. 3, Minn. R. 7007.1150-7007.1500, Minn. R. 7011.7000]

EQUI 78 MR916 Lime Kiln TRS


5.26.1 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]

5.26.2 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]

5.26.3 Sulfur - Total Reduced including H2S: Emissions Monitoring: The owner or operator shall use a CEMS to measure emissions from EQUI 13. [Minn. R. 7017.1006]

5.26.4 Certification Test Plan due 30 days before Certification


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation Test. Certification Test Pretest Meeting due 7 days before Certification Test. Certification Test Report due 45 days after Certification Test. The Test Plan and Test Report must be submitted in a format specified by the commissioner. [Minn. R. 7017.1060, subp. 1-3, Minn. R. 7017.1080]

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

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

5.26.7 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 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. [Minn. R. 7017.1170, subp. 2]

5.26.8 CEMS Daily Calibration Drift (CD) Test: The CD shall be quantified and recorded at zero (low-level) and upscale (high-level) gas concentrations at least once daily according to the procedures listed in Minn. R. 7017.1170, subp. 3(A) and (B), 40 CFR Section 60.13(d)(1) or 40 CFR pt. 75, Appendix B as applicable for each pollutant concentration, each diluent monitor, and for each monitor range. If no span value is specified in the applicable requirement or in a compliance document, the Permittee shall use a span value equivalent to 1.5 times the emission limit. [Minn. R.


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation 7017.1170, subp. 3]

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

5.26.10 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. [Minn. R. 7017.1050, subp. 1]

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

EQUI 79 MR320 Recovery

Furnace Opacity COM - Continuous Opacity Monitor

5.27.1 Continuous operation. COMS must be operated and data recorded during all periods of unit operation including periods of unit start-up, shutdown, or malfunction except for periods of acceptable monitor downtime. This requirement to operate the monitor applies whether or not a numerical emission limit applies during these periods. A COMS must not be bypassed except in emergencies where failure to bypass the COMS would endanger human health, safety, or plant equipment. Acceptable monitor downtime includes reasonable periods as listed in Items A, B, C and D of Minn. R. 7017.1090. [Minn. R. 7017.1090]

5.27.2 Emissions Monitoring: The owner or operator shall use a COMS to measure Opacity from EQUI 9. [Minn. R. 7017.1006]

5.27.3 Monitoring Data: All COMS data must be reduced to six-minute averages. A six minute average is valid only if it contains data from at least five minutes within the averaging period. COMS data shall be reduced and calculated as outlined in Minn. R. 7017.1200, subp. 3. [Minn. R. 7017.1200, subp. 1-3]

5.27.4 The Permittee shall perform zero alignment as described in Procedure 3, section 10.3 of 40 CFR Pt. 60, Appendix F. [Minn. R. 7017.1215]

5.27.5 COMS Daily Calibration Drift Test: The owner or operator of a COMS shall conduct daily instrument zero and upscale drift checks according to Procedure 3, section 10.1 of 40 CFR Pt. 60, Appendix F. [Minn. R.



5.27.6 COMS Calibration Error Audit Results Summary: due 30 days after end of each calendar quarter in which the COMS calibration error audit was completed. [Minn. R. 7017.1220]

5.27.7 COMS Certification/Recertification Test: due 90 days after the first excess emissions report required for the COMS or any change which invalidates the monitor's certification status as outlined in Minn. R. 7017.1050, subp. 2. [Minn. R. 7017.1050, subp. 1]

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

5.27.9 QA Plan: the facility owner or operator must conduct quality assurance and quality control as specified in Procedure 3 - Quality Assurance Requirements for Continuous Opacity Monitoring Systems at Stationary Sources, 40 CFR Pt. 60, Appendix F. [Minn. R. 7017.1215]

EQUI 80 MR432 Boiler 2 Opacity


5.28.1 Emissions Monitoring: The owner or operator shall use a COMS to measure Opacity from EQUI 16. Additional monitoring requirements are also located at EQUI 16. [Minn. R. 7017.1006]

5.28.2 Continuous operation. COMS must be operated and data recorded during all periods of unit operation including periods of unit start-up, shutdown, or malfunction except for periods of acceptable monitor downtime. This requirement to operate the monitor applies whether or not a numerical emission limit applies during these periods. A COMS must not be bypassed except in emergencies where failure to bypass the COMS would endanger human health, safety, or plant equipment. Acceptable monitor downtime includes reasonable periods as listed in Items A, B, C and D of Minn. R. 7017.1090. [Minn. R. 7017.1090]

5.28.3 Monitoring Data: All COMS data must be reduced to six-minute averages. A six minute average is valid only if it contains data from at least five minutes within the averaging period. COMS data shall be reduced and calculated as outlined in Minn. R. 7017.1200, subp. 3. [Minn. R. 7017.1200, subp. 1-3]


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation 5.28.4 The Permittee shall perform zero alignment as

described in Procedure 3, section 10.3 of 40 CFR Pt. 60, Appendix F. [Minn. R. 7017.1215]

5.28.5 COMS Daily Calibration Drift Test: The owner or operator of a COMS shall conduct daily instrument zero and upscale drift checks according to Procedure 3, section 10.1 of 40 CFR Pt. 60, Appendix F. [Minn. R. 7017.1215]

5.28.6 COMS Calibration Error Audit Results Summary: due 30 days after end of each calendar quarter in which the COMS calibration error audit was completed. [Minn. R. 7017.1220]

5.28.7 COMS Certification/Recertification Test: due 90 days after the first excess emissions report required for the COMS or any change which invalidates the monitor's certification status as outlined in Minn. R. 7017.1050, subp. 2. [Minn. R. 7017.1050, subp. 1]

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

5.28.9 QA Plan: the facility owner or operator must conduct quality assurance and quality control as specified in Procedure 3 - Quality Assurance Requirements for Continuous Opacity Monitoring Systems at Stationary Sources, 40 CFR Pt. 60, Appendix F. [Minn. R. 7017.1215]


Furnace NOx CEM - Continuous Emission Monitor



5.29.3 Nitrogen Oxides: Emissions Monitoring: The owner or operator shall use a CEMS to measure emissions from EQUI 9. [Minn. R. 7017.1006]

5.29.4 Certification Test Plan due 30 days before Certification Test. Certification Test Pretest Meeting due 7 days before Certification Test.


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation Certification Test Report due 45 days after Certification Test. The Test Plan and Test Report must be submitted in a format specified by the commissioner. [Minn. R. 7017.1060, subp. 1-3, Minn. R. 7017.1080]




5.29.8 CEMS Daily Calibration Drift (CD) Test: The CD shall be quantified and recorded at zero (low-level) and upscale (high-level) gas concentrations at least once daily according to the procedures listed in Minn. R. 7017.1170, subp. 3(A) and (B), 40 CFR Section 60.13(d)(1) or 40 CFR pt. 75, Appendix B as applicable for each pollutant concentration, each diluent monitor, and for each monitor range. If no span value is specified in the applicable requirement or in a compliance document, the Permittee shall use a span value equivalent to 1.5 times the emission limit. [Minn. R. 7017.1170, subp. 3]

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


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation [Minn. R. 7017.1180, subp. 2]




Furnace TRS CEM - Continuous Emission Monitor



5.30.3 Sulfur - Total Reduced including H2S: Emissions Monitoring: The owner or operator shall use a CEMS to measure emissions from EQUI 9. [Minn. R. 7017.1006]

5.30.4 Certification Test Plan due 30 days before Certification Test. Certification Test Pretest Meeting due 7 days before Certification Test. Certification Test Report due 45 days after Certification Test. The Test Plan and Test Report must be submitted in a format specified by the commissioner. [Minn. R. 7017.1060, subp. 1-3, Minn. R. 7017.1080]


5.30.6 Monitoring Data: All data points collected by a CEMS shall be used to calculate individual hourly emission


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation averages unless another applicable requirement requires more frequent averaging. In order for an hour of data to be considered, it must contain the following minimum number of data points: A. four data points, equally spaced, if the emission unit operated during the entire hour; B. two data points, at least 15 minutes apart, during periods of monitor calibration or routine maintenance; C. one data point if the emission unit operated for 15 minutes or less during the hour. [Minn. R. 7017.1160, subp. 1-2]







Furnace CO CEM - Continuous


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation Emission Monitor



5.31.3 Carbon Monoxide: Emissions Monitoring: The owner or operator shall use a CEMS to measure emissions from EQUI 9. [Minn. R. 7017.1006]




5.31.7 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 include the manufacturer's spare parts list for each CEMS and require that those parts be kept at the facility unless the


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation Commissioner gives written approval to exclude specific spare parts from the list. [Minn. R. 7017.1170, subp. 2]





EQUI 90 MR915 Boiler 2 CO




5.32.3 Carbon Monoxide: Emissions Monitoring: The owner or operator shall use a CEMS to measure emissions from EQUI 16. [Minn. R. 7017.1006]

5.32.4 Certification Test Plan due 30 days before Certification Test. Certification Test Pretest Meeting due 7 days before Certification Test. Certification Test Report due 45 days after Certification Test.


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation The Test Plan and Test Report must be submitted in a format specified by the commissioner. [Minn. R. 7017.1060, subp. 1-3, Minn. R. 7017.1080]





5.32.9 Relative Accuracy Test Audit (RATA) Notification: due 60 days before CEMS Relative Accuracy Test Audit (RATA). This is the notification required by 40 CFR pt. 63, subp DDDDD.


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation Minn. R. 7017.1170, subp. 2 requires a notification of 30 days. [40 CFR 63.7575(2)(i), 40 CFR 63.8(e)(2)]



EQUI 109 MR421 Boiler 1 O2




5.33.3 Oxygen: Emissions Monitoring: The owner or operator shall use a CEMS to measure emissions from EQUI 15. [Minn. R. 7017.1006]



5.33.6 Monitoring Data: All data points collected by a CEMS shall be used to calculate individual hourly emission


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation averages unless another applicable requirement requires more frequent averaging. In order for an hour of data to be considered, it must contain the following minimum number of data points: A. four data points, equally spaced, if the emission unit operated during the entire hour; B. two data points, at least 15 minutes apart, during periods of monitor calibration or routine maintenance; C. one data point if the emission unit operated for 15 minutes or less during the hour. [Minn. R. 7017.1160, subp. 1-2]






EQUI 110 MR420 Boiler 1 NOx

CEM - Continuous Emission


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation Monitor







5.34.7 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 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


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation spare parts from the list. [Minn. R. 7017.1170, subp. 2]









5.35.3 Oxygen: Emissions Monitoring: The owner or operator shall use a CEMS to measure emissions from EQUI 17. [40 CFR pt. 60, subp. Db, Minn. R. 7017.1010, subp 1]

5.35.4 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), Minn. R. 7017.1050, subp. 1]

5.35.5 Certification Test Plan due 30 days before Certification Test.


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation Certification Test Pretest Meeting due 7 days before Certification Test. Certification Test Report due 45 days after Certification Test. The Test Plan and Test Report must be submitted in a format specified by the commissioner. [40 CFR 60.7(a)(5), Minn. R. 7017.1060, subp. 1-3, Minn. R. 7017.1080]

5.35.6 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]

5.35.7 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]

5.35.8 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]

5.35.9 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]

5.35.10 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


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation the monitoring sample, measurement or report. Records shall be kept at the source. [40 CFR 60.7(f), Minn. R. 7017.1130]

5.35.11 CEMS Monitor Design: Each CEMS shall be designed to complete a minimum of one cycle of sampling, analyzing, and data recording in each 15-minute period. [40 CFR 60.13(e)(2)]


Furnace O2 CEM - Continuous Emission Monitor






5.36.6 Monitoring Data: All data points collected by a CEMS shall be used to calculate individual hourly emission averages unless another applicable requirement requires more frequent averaging. In order for an hour of data to be considered, it must contain the following minimum number of data points: A. four data points, equally spaced, if the emission unit


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation operated during the entire hour; B. two data points, at least 15 minutes apart, during periods of monitor calibration or routine maintenance; C. one data point if the emission unit operated for 15 minutes or less during the hour. [Minn. R. 7017.1160, subp. 1-2]






EQUI 125 MR327 Lime Kiln O2



5.37.2 Cylinder Gas Audit (CGA) Results Summary: due 30 days


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation after end of each calendar quarter in which a CGA was conducted. [Minn. R. 7017.1180, subp. 1]






5.37.8 CEMS Daily Calibration Drift (CD) Test: The CD shall be quantified and recorded at zero (low-level) and upscale (high-level) gas concentrations at least once daily according to the procedures listed in Minn. R. 7017.1170, subp. 3(A) and (B), 40 CFR Section


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation 60.13(d)(1) or 40 CFR pt. 75, Appendix B as applicable for each pollutant concentration, each diluent monitor, and for each monitor range. If no span value is specified in the applicable requirement or in a compliance document, the Permittee shall use a span value equivalent to 1.5 times the emission limit. [Minn. R. 7017.1170, subp. 3]




EQUI 128 MR440 Boiler 3 NOX




5.38.3 Nitrogen Oxides: Emissions Monitoring: The owner or operator shall use a CEMS to measure emissions from EQUI 17. [40 CFR pt. 60, subp. Db, Minn. R. 7017.1010, subp 1]

5.38.4 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), Minn. R. 7017.1050, subp. 1]

5.38.5 Certification Test Plan due 30 days before Certification Test. Certification Test Pretest Meeting due 7 days before Certification Test. Certification Test Report due 45 days after Certification Test. The Test Plan and Test Report must be submitted in a


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation format specified by the commissioner. [40 CFR 60.7(a)(5), Minn. R. 7017.1060, subp. 1-3, Minn. R. 7017.1080]

5.38.6 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]

5.38.7 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]

5.38.8 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]

5.38.9 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]

5.38.10 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]

5.38.11 CEMS Monitor Design: Each CEMS shall be designed to complete a minimum of one cycle of sampling, analyzing, and data recording in each 15-minute period.


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation [40 CFR 60.13(e)(2)]









5.39.7 QA Plan: Develop and implement a written quality


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation 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 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. [Minn. R. 7017.1170, subp. 2]










5.40.4 Certification Test Plan due 30 days before Certification Test.


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation Certification Test Pretest Meeting due 7 days before Certification Test. Certification Test Report due 45 days after Certification Test. The Test Plan and Test Report must be submitted in a format specified by the commissioner. [Minn. R. 7017.1060, subp. 1-3, Minn. R. 7017.1080]






Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation 5.40.9 Relative Accuracy Test Audit (RATA) Notification: due 30

days before CEMS Relative Accuracy Test Audit (RATA). [Minn. R. 7017.1180, subp. 2]











Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation 5.41.6 Monitoring Data: All data points collected by a CEMS

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






EQUI 940 EU917 Intermediate

Chip Cyclone


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation 5.42.1 Particulate Matter <= 3.0 pounds per hour 3-hour

average, as determined by performance test. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.42.2 PM < 10 micron <= 2.9 pounds per hour 3-hour average, as determined by performance test. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.42.3 Periodic Monitoring: the Permittee shall perform proper maintenance of the cyclone so as to prevent excessive amounts of particulate matter from being emitted from STRU 82. [Minn. R. 7007.0800, subp. 4]

EQUI 944 EU602 Wastewater

Treatment Plant Cooling Tower

5.43.1 Wastewater: Process Throughput <= 1700 million gallons per year 12-month rolling sum. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.43.2 Monthly Recordkeeping -- wastewater process rate By the 15th of the month, the Permittee shall calculate and record the following: 1) The amount of wastewater processed for the previous calendar month 2) The 12-month rolling sum of the amount of wastewater processed for the previous 12-month period by summing the monthly emissions data for the previous 12 months. [Minn. R. 7007.0800, subp. 5, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

EQUI 945 EU322 Smelt

Dissolving Tank

5.44.1 The Permittee shall limit emissions of Particulate Matter <= 7.3 pounds per hour 3-hour average, as determined by performance test. This is based on an EPA approved limit from a letter dated September 29, 2008 (and the Total Facility BLS limit at that time). [40 CFR 63.862(a)(1)(i)(B), Title I Condition: 40 CFR 52.21(b)(2)(i)(netting) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

5.44.2 The Permittee shall limit emissions of Particulate Matter <= 0.20 pounds per ton of BLS (black liquor solids). This is the 40 CFR pt. 60, subp. BB and 40 CFR pt. 63, subp. MM limit. [40 CFR 60.282(a)(2) & (4), 40 CFR 63.862(a)(1)(i)(B), Minn. R. 7011.2450, Minn. R. 7011.7700]

5.44.3 The Permittee shall limit emissions of PM < 10 micron


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation <= 7.3 pounds per hour 3-hour average, as determined by performance test. This is based on an EPA approved limit from a letter dated September 29, 2008 (and the Total Facility BLS limit at that time). [40 CFR 63.862(a)(1)(i)(B), Title I Condition: 40 CFR 52.21(b)(2)(i)(netting) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

5.44.4 The Permittee shall limit Opacity <= 20 percent opacity 6-minute average. [Minn. R. 7007.0800, subp. 2]

5.44.5 The Permittee shall limit emissions of Nitrogen Oxides <= 0.033 pounds per ton of BLS (black liquor solids) produced. [Title I Condition: 40 CFR 52.21(o)(visibility) & Minn. R. 7007.3000]

5.44.6 The Permittee shall limit emissions of Sulfur Dioxide <= 4.3 pounds per hour 3-hour average, as determined by performance test. (this is equivalent to 0.090 lb/ton BLS). [Title I Condition: 40 CFR 52.21(b)(2)(i)(netting) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

5.44.7 The Permittee shall limit emissions of Volatile Organic Compounds <= 0.090 pounds per ton of BLS (black liquor solids) measured as carbon, excluding methane (this is equivalent to 4.3 lb/hr). [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.44.8 The Permittee shall limit emissions of Sulfur - Total Reduced including H2S <= 0.033 pounds per ton of BLS (black liquor solids) measured as H2S The BACT limit is the same as the NSPS limit. [40 CFR 60.283(a)(4), Minn. R. 7011.2450, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.44.9 The owner or operator must maintain records of parameter monitoring data required under 40 CFR Section 63.864, including any period when the operating parameter levels were inconsistent with the levels established during the initial performance test, with a brief explanation of the cause of the deviation, the time the deviation occurred, the time corrective action was initiated and completed, and the corrective action taken. [40 CFR 63.866(c)(3), Minn. R. 7011.7700]

5.44.10 NOx Emissions Calculation: The Permittee shall calculate NOx emissions on a semi-annual basis. The NOx emission factor shall be obtained from the most recent MPCA approved performance test. To calculate NOx emissions, the Permittee shall multiply the emission factor by the production rate of black liquor solids (virgin bone dried basis). The NOx emissions shall be calculated and converted to a tons/day basis for determining the total NOx emissions from the facility and comparison to the NOx cap (COMG 5). [Minn. R.


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation 7007.0800, subp. 6, Title I Condition: 40 CFR 52.21(o)(visibility) & Minn. R. 7007.3000]

EQUI 949 Boiler 2 NOX &

SO2 CEM



5.45.3 Nitrogen Oxides: Emissions Monitoring: The owner or operator shall use a CEMS to measure emissions from EQUI 16. This unit also monitors SO2 emissions. [Minn. R. 7017.1006]




5.45.7 QA Plan: Develop and implement a written quality assurance plan that covers each CEMS. The plan shall be


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation on site and available for inspection within 30 days after monitor certification. 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. [Minn. R. 7017.1170, subp. 2]





STRU 20 SV173 Brown Stock

Decker

5.46.1 The Permittee shall limit emissions of Sulfur Dioxide <= 0.020 pounds per ton 3-hour average of air dried unbleached pulp. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.46.2 The Permittee shall limit emissions of Volatile Organic Compounds <= 0.20 pounds per ton 3-hour average of air dried unbleached pulp, measured as carbon, excluding methane. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.46.3 The Permittee shall limit emissions of Sulfur - Total Reduced including H2S <= 0.12 pounds per ton 3-hour average of air dried unbleached pulp, measured as H2S. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.46.4 Pulping System Emissions Control: The emissions from


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation the pulping system shall meet the requirements specified in 40 CFR Section 63.443(a)(1)(ii) through (iv), or as specified in 40 CFR Section 63.447 Clean Condensate Alternative. [40 CFR 63.446, Minn. R. 7011.7700]

5.46.5 The Permittee shall limit emissions of HAPs - Total <= 400 parts per million by weight (process water). For purposes of complying with the kraft pulping condensate requirements in 40 CFR Section 63.446, the Permitee chooses to measure the total HAP concentration as methanol (see 40 CFR Section 63.457(f)(2)). [40 CFR 63.443(a)(1)(iv)(B), Minn. R. 7011.7700]

STRU 75 SV903 Combined

SV220 and SV240 (ClO2 Generator & Bleach Plant)

5.47.1 STRU 75 is an additional stack to combine stack vent 220 (ClO2 generator Delta description) and stack vent 240 (Bleach plant Delta description) that has been installed to more accurately match stack parameters as modeled for Air Toxics Review. SV 220 and SV 240 (no Tempo IDs) have been removed from the facility description and have been replaced with STRU 75. [Minn. R. 7007.0800, subp. 2]

TREA 1 CE320 Electrostatic

Precipitator - Recovery Furnace

5.48.1 ESP monitoring: The COMS for EQUI 9 shall be used to assess proper operation of this ESP. [40 CFR 64.7(a), Minn. R. 7007.0800, subp. 2, Minn. R. 7017.0200]

5.48.2 The Permittee shall vent emissions from EQUI 9 to TREA 1 whenever EQUI 9 operates, and operate and maintain TREA 1 at all times that any emissions are vented to TREA 1. The Permittee shall document periods of non-operation of the control equipment TREA 1 whenever EQUI 9 is operating. [Minn. R. 7007.0800, subp. 14, Minn. R. 7007.0800, subp. 2]

5.48.3 Opacity <= 13 percent opacity 3-hour block average. Opacity in excess of this limit shall be considered an excursion under 40 CFR Section 64.6(c)(2). [40 CFR 64.3, Minn. R. 7017.0200]

5.48.4 Opacity: Continuous Monitoring: The Permittee shall continuously, or at a minimum once every 15 minutes, monitor the opacity of the ESP exhaust. See Subject Item EQUI 79 for specific COMS operating


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation requirements. [40 CFR 64.3(b)(4)(ii), Minn. R. 7017.0200]

5.48.5 Inspections: At least every two years, or more frequently if required by the manufacturer, the Permittee shall inspect the control equipment components not covered by the quarterly inspections. This includes, but is not limited to, components that are not subject to wear or plugging including structural components, housings, and hoods. The Permittee shall maintain a written record of the inspection and any corrective actions taken resulting from the inspection. [40 CFR 64.3, Minn. R. 7017.0200]

5.48.6 Corrective Actions: The Permittee shall take corrective action as soon as possible if any of the following occur: - the monitored opacity, averaged over any 3-hour period, exceeds 13%; or - the ESP or any of its components are found during the inspections to need repair. Corrective actions shall return operation to within the permitted range and/or include completion of necessary repairs identified during the inspection, as applicable. Corrective actions include, but are not limited to, those outlined in the O & M Plan for the ESP. The Permittee shall keep a record of the type and date of any corrective action taken for the ESP. [40 CFR 64.7(6), Minn. R. 7017.0200]

5.48.7 If the Permittee replaces TREA 1, the replacement control must meet or exceed the control efficiency requirements of TREA 1 as well as comply with all other requirements of TREA 1. Prior to making such a change, the Permittee shall apply for and obtain the appropriate permit amendment, as applicable. If no amendment is needed for the replacement, the Permittee shall submit an electronic notice to the Agency using Form CR-05. The notice must be received by the Agency seven working days prior to the commencement/start of replacement. [40 CFR 64.7, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

5.48.8 Documentation of Need for Improved Monitoring: If the Permittee fails to achieve compliance with an emission limitation or standard for which the monitoring did not provide an indication of an excursion or exceedance while providing valid data, or the results of compliance or performance testing document a need to modify the existing opacity indicator range, the Permittee shall promptly notify the MPCA and, if necessary, submit a permit amendment application to address the necessary monitoring change. [40 CFR 64.7(e), Minn. R. 7017.0200]


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation 5.48.9 As required by 40 CFR Section 64.9(a)(2), for the Semi-

Annual Deviations Report required by this permit and/or the Notification of Deviations Endangering Human Health and the Environment required by this permit, as applicable, the Permittee shall include the following related to the monitoring identified as required by 40 CFR pt. 64: 1) Summary information on the number, duration, and cause of excursions or exceedances, as applicable, and the corrective action taken; and 2) Summary information on the number, duration, and cause for monitor downtime incidents. [40 CFR 64.9(a)(2), Minn. R. 7017.0200]

5.48.10 The Permittee shall maintain records of monitoring data, monitor performance data, corrective actions taken, and other supporting information required to be maintained. The Permittee may maintain records on alternative media, provided that the use of such alternative media allows for expeditious inspection and review, and does not conflict with other applicable recordkeeping requirements. [40 CFR 64.9(b), Minn. R. 7017.0200]

5.48.11 The Permittee shall operate and maintain the electrostatic precipitator (ESP) in accordance with the Operation and Maintenance (O & M) Plan. The Permittee shall keep copies of the O & M Plan available onsite for use by staff and MPCA staff. [Minn. R. 7007.0800, subp. 14]

5.48.12 Monitoring Equipment: The necessary monitoring equipment must be installed, in use, and properly maintained, including maintaining the necessary parts for routine repairs of the monitoring equipment, whenever operation of the monitored control equipment is required. [40 CFR 64.7(b), Minn. R. 7017.0200]

5.48.13 Periodic Inspections: At least once per calendar quarter, or more frequently if required by the manufacturer, the Permittee shall inspect the control equipment components that are subject to wear or plugging, for example: bearings, belts, hoses, fans, nozzles, orifices, and ducts. The Permittee shall maintain a written record of the inspection and any corrective actions taken resulting from the inspection. [40 CFR 64.3, Minn. R. 7017.0200]

TREA 2 CE322 Venturi

Scrubber - Smelt Dissolving Tank

5.49.1 Install, calibrate, maintain, and operate a continuous parameter monitoring system (CPMS) that can be used


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation to determine and record the pressure drop across the scrubber and the scrubbing liquid flow rate at least once every successive 15-minute period using the procedures in 63.8(c), as well as the procedures in paragraphs (e)(10)(i) and (ii). The owner or operator of each affected source or process unit that uses an ESP, wet scrubber, RTO, or fabric filter may monitor alternative control device operating parameters subject to prior written approval by the Administrator. [40 CFR 63.864(e)(10)&(13), 40 CFR 64.7(a), Minn. R. 7011.7700]

5.49.2 Install, calibrate, maintain, and operate a monitoring device for the continuous measurement (at least once every 15 minutes) of the pressure loss of the gas stream through the control equipment. The monitoring device used for the continuous measurement of the pressure drop of the gas stream across the scrubber must be certified by the manufacturer to be accurate to within a gage pressure of +/-2 inches of water gage pressure. [40 CFR 60.284(b)(2)(i), 40 CFR 63.864(e), 40 CFR 64.7(a), Minn. R. 7011.2540]

5.49.3 Install, calibrate, maintain, and operate a monitoring device for the continuous measurement (at least once every 15 minutes) of the scrubbing liquid flow rate. The monitoring device used for continuous measurement of the scrubbing liquid flow rate must be certified by the manufacturer to be accurate within +/-5 percent of the design scrubbing liquid flow rate. [40 CFR 63.864(e), 40 CFR 64.7(a), Minn. R. 7011.7700]

5.49.4 Install, calibrate, maintain, and operate a monitoring device for the continuous measurement of the scrubbing liquid supply pressure to the control equipment. The monitoring device is to be certified by the manufacturer to be accurate within +/-15 percent of design scrubbing liquid supply pressure. The pressure sensor or tap is to be located close to the scrubber liquid discharge point. The Administrator may be consulted for approval of alternative locations. [40 CFR 60.284(b)(2)(ii), 40 CFR 64.7(a), Minn. R. 7011.2450]

5.49.5 Record once per shift, measurements obtained from the monitoring device for the continuous measurement of the pressure loss of the gas stream through the control equipment and from the monitoring device for the continuous measurement of the scrubbing liquid supply pressure to the control equipment. [40 CFR 60.284(c)(4), Minn. R. 7011.2450]

5.49.6 Pressure Drop >= 10 inches of water column 3-hour block average or as determined during the most recent performance test. Three-hour block average is the average scrubber pressure drop in each three-hour


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation block. Downtime of 15 or more minutes is not to be included as operating time. [40 CFR 64.3(a), Minn. R. 7017.2025, subp. 3]

5.49.7 Liquid Flow Rate >= 81 gallons per minute 3-hour block average, unless a new limit is set pursuant to Minn. R. 7017.2025, subp. 3, based on the values recorded during the most recent MPCA-approved performance test where compliance was demonstrated. The new limit shall be implemented upon receipt of the Notice of Compliance letter granting preliminary approval. The limit is final upon issuance of a permit amendment incorporating the change. [40 CFR 64.3(a), Minn. R. 7017.2025, subp. 3]

5.49.8 Corrective Actions: If the monitored parameter is out of the range as described above, the Permittee shall follow the facility SSM Plan and/or the O&M Plan and perform the necessary corrective action(s) as soon as possible to get the parameters back into the correct range. The Permittee shall keep a record of the type and date of all corrective actions taken. [40 CFR 63.864(k), 40 CFR 63.867(c), Minn. R. 7007.0800, subp. 14, Minn. R. 7007.0800, subp. 5]

5.49.9 After completion of the Initial Performance test, the Permittee is in violation of the Subpart MM Standards of 40 CFR Section 63.862 if the Smelt Dissolving Tank Vent accumulates 6 or more 3-hour operating parameter exceedances within any 6-month calendar reporting period. For purposes of determining the number of monitoring exceedances, no more than one exceedance shall be attributed in any given 24-hour period. [40 CFR 63.864(k)(2)(iii), 40 CFR 63.864(k)(3)]

5.49.10 On-going compliance provisions. Smelt Dissolving Tank units are required to implement corrective action, when any 3-hour average parameter value is outside the range of values established in paragraph (j) of this section. [40 CFR 63.864(k)(1)(i)]

5.49.11 The Permittee shall vent emissions from EQUI 945 to TREA 2 whenever EQUI 945 operates, and operate and maintain TREA 2 at all times that any emissions are vented toTREA 2. The Permittee shall document periods of non-operation of the control equipment TREA 2 whenever EQUI 945 is operating. TREA 3 (Venturi Scrubber) is the backup treatment for TREA 2. This requirement applies only when EQUI 945 is venting to TREA 2. [Minn. R. 7007.0800, subp. 14, Minn. R. 7007.0800, subp. 2]

5.49.12 If the Permittee replaces TREA 2, the replacement control must meet or exceed the control efficiency requirements of TREA 2 as well as comply with all other requirements of TREA 2. Prior to making such a change,


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation the Permittee shall apply for and obtain the appropriate permit amendment, as applicable. If no amendment is needed for the replacement, the Permittee shall submit an electronic notice to the Agency using Form CR-05. The notice must be received by the Agency seven working days prior to the commencement/start of replacement. [40 CFR 64.7, Title I Condition: 40 CFR 52.21(b)(2)(i)(netting) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

5.49.13 As required by 40 CFR Section 64.9(a)(2), for the Semi-Annual Deviations Report required by this permit and/or the Notification of Deviations Endangering Human Health and the Environment required by this permit, as applicable, the Permittee shall include the following related to the monitoring identified as required by 40 CFR pt. 64: 1) Summary information on the number, duration, and cause of excursions or exceedances, as applicable, and the corrective action taken; and 2) Summary information on the number, duration, and cause for monitor downtime incidents. [40 CFR 64.9(a)(2), Minn. R. 7017.0200]


5.49.15 The Permittee shall operate and maintain the scrubber in accordance with the Operation and Maintenance (O & M) Plan. The Permittee shall keep copies of the O & M Plan available onsite for use by staff and MPCA staff. [Minn. R. 7007.0800, subp. 14]

5.49.16 Monitoring Equipment: The Permittee shall install and maintain the necessary monitoring equipment for measuring and recording pressure drop and liquid flow rate as required by this permit. The monitoring equipment must be installed, in use, and properly maintained when the monitored scrubber is in operation. [40 CFR 64.7(b), Minn. R. 7017.0200]

5.49.17 The Permittee shall calibrate the gauges at least once every 12 months and shall maintain a written record of any action resulting from the calibration. [40 CFR 64.3, Minn. R. 7017.0200]



Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation Scrubber - Smelt Dissolving Tank

5.50.1 Install, calibrate, maintain, and operate a continuous parameter monitoring system (CPMS) that can be used to determine and record the pressure drop across the scrubber and the scrubbing liquid flow rate at least once every successive 15-minute period using the procedures in 63.8(c), as well as the procedures in paragraphs (e)(10)(i) and (ii). The owner or operator of each affected source or process unit that uses an ESP, wet scrubber, RTO, or fabric filter may monitor alternative control device operating parameters subject to prior written approval by the Administrator. [40 CFR 63.864(e)(10)&(13), 40 CFR 64.7(a), Minn. R. 7011.7700]

5.50.2 Install, calibrate, maintain, and operate a monitoring device for the continuous measurement (at least once every 15 minutes) of the pressure loss of the gas stream through the control equipment. The monitoring device used for the continuous measurement of the pressure drop of the gas stream across the scrubber must be certified by the manufacturer to be accurate to within a gage pressure of +/-2 inches of water gage pressure. [40 CFR 60.284(b)(2)(i), 40 CFR 63.864(e), 40 CFR 64.7(a), Minn. R. 7011.2540]

5.50.3 Install, calibrate, maintain, and operate a monitoring device for the continuous measurement (at least once every 15 minutes) of the scrubbing liquid flow rate. The monitoring device used for continuous measurement of the scrubbing liquid flow rate must be certified by the manufacturer to be accurate within +/-5 percent of the design scrubbing liquid flow rate. [40 CFR 63.864(e), 40 CFR 64.7(a), Minn. R. 7011.7700]


5.50.5 Record once per shift, measurements obtained from the monitoring device for the continuous measurement of the pressure loss of the gas stream through the control equipment and from the monitoring device for the continuous measurement of the scrubbing liquid supply pressure to the control equipment. [40 CFR


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation 60.284(c)(4), Minn. R. 7011.2450]

5.50.6 Pressure Drop >= 10 inches of water column 3-hour block average or as determined during the most recent performance test. Three-hour block average is the average scrubber pressure drop in each three-hour block. Downtime of 15 or more minutes is not to be included as operating time. [40 CFR 64.3(a), Minn. R. 7017.2025, subp. 3]

5.50.7 Liquid Flow Rate >= 81 gallons per minute 3-hour block average, unless a new limit is set pursuant to Minn. R. 7017.2025, subp. 3, based on the values recorded during the most recent MPCA-approved performance test where compliance was demonstrated. The new limit shall be implemented upon receipt of the Notice of Compliance letter granting preliminary approval. The limit is final upon issuance of a permit amendment incorporating the change. [40 CFR 64.3(a), Minn. R. 7017.2025, subp. 3]

5.50.8 Corrective Actions: If the monitored parameter is out of the range as described above, the Permittee shall follow the facility SSM Plan and/or the O&M Plan and perform the necessary corrective action(s) as soon as possible to get the parameters back into the correct range. The Permittee shall keep a record of the type and date of all corrective actions taken. [40 CFR 63.864(k), 40 CFR 63.867(c), Minn. R. 7007.0800, subp. 14, Minn. R. 7007.0800, subp. 5]

5.50.9 After completion of the Initial Performance test, the Permittee is in violation of the Subpart MM Standards of 40 CFR Section 63.862 if the Smelt Dissolving Tank Vent accumulates 6 or more 3-hour operating parameter exceedances within any 6-month calendar reporting period. For purposes of determining the number of monitoring exceedances, no more than one exceedance shall be attributed in any given 24-hour period. [40 CFR 63.864(k)(2)(iii), 40 CFR 63.864(k)(3)]

5.50.10 On-going compliance provisions. Smelt Dissolving Tank units are required to implement corrective action, when any 3-hour average parameter value is outside the range of values established in paragraph (j) of this section. [40 CFR 63.864(k)(1)(i)]

5.50.11 TREA 2 (Venturi Scrubber) is the primary treatment for EQUI 945. TREA 3 is used as a backup. This requirement applies only when EQUI 945 is venting to TREA 3. The Permittee shall vent emissions from EQUI 945 to TREA 3 whenever EQUI 945 operates, and operate and maintain TREA 3 at all times that any emissions are vented to TREA 3. The Permittee shall document periods of non-operation of the control equipment TREA 3 whenever EQUI 945 is operating. [Title I


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation Condition: Avoid major source under 40 CFR 52.21(b)(1)(i) and Minn. R. 7007.3000]

5.50.12 If the Permittee replaces TREA 3, the replacement control must meet or exceed the control efficiency requirements of TREA 3 as well as comply with all other requirements of TREA 3. Prior to making such a change, the Permittee shall apply for and obtain the appropriate permit amendment, as applicable. If no amendment is needed for the replacement, the Permittee shall submit an electronic notice to the Agency using Form CR-05. The notice must be received by the Agency seven working days prior to the commencement/start of replacement. [40 CFR 64.7, Title I Condition: 40 CFR 52.21(b)(2)(i)(netting) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(modeling ) & MInn. R. 7007.3000]




5.50.16 Monitoring Equipment: The Permittee shall install and maintain the necessary monitoring equipment for measuring and recording pressure drop and liquid flow rate as required by this permit. The monitoring equipment must be installed, in use, and properly maintained when the monitored scrubber is in operation. [40 CFR 64.7(b), Minn. R. 7017.0200]

5.50.17 The Permittee shall calibrate the gauges at least once


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation every 12 months and shall maintain a written record of any action resulting from the calibration. [40 CFR 64.3, Minn. R. 7017.0200]

TREA 5 CE431 Electrostatic

Precipitator - Boiler 2

5.51.1 Continuous Monitoring: The Permittee shall continuously, or at a minimum once every 15 minutes, monitor the opacity of the ESP exhaust. See Subject Item EQUI 80 for specific COMS operating requirements. [40 CFR 64.3(b)(4)(ii), Minn. R. 7017.0200]

5.51.2 The Permittee shall vent emissions from EQUI 16 to TREA 5 whenever EQUI 16 operates, and operate and maintain TREA 5 at all times that any emissions are vented to TREA 5. The Permittee shall document periods of non-operation of the control equipment TREA 5 whenever EQUI 16 is operating. [Minn. R. 7007.0800, subp. 14, Minn. R. 7007.0800, subp. 2]

5.51.3 Opacity <= 8.5 percent opacity 3-hour block average. Opacity in excess of this limit shall be considered an excursion under 40 CFR Section 64.6(c)(2). [40 CFR 64.3, Minn. R. 7017.0200]

5.51.4 Opacity: Continuous Monitoring: The Permittee shall continuously, or at a minimum once every 15 minutes, monitor the opacity of the ESP exhaust. See Subject Item EQUI 80 for specific COMS operating requirements. [40 CFR 64.3(b)(4)(ii), Minn. R. 7017.0200]

5.51.5 Inspections: At least once every two years, or more frequently if required by the manufacturer, the Permittee shall inspect the control equipment components not covered by the quarterly inspections. This includes, but is not limited to, components that are not subject to wear or plugging including structural components, housings, and hoods. The Permittee shall maintain a written record of the inspection and any corrective actions taken resulting from the inspection. [40 CFR 64.3, Minn. R. 7017.0200]

5.51.6 Corrective Actions: The Permittee shall take corrective action as soon as possible if any of the following occur: - the monitored opacity, averaged over any 3-hour period, exceeds 8.5%; or - the ESP or any of its components are found during the inspections to need repair. Corrective actions shall return operation to within the permitted range and/or include completion of necessary repairs identified during the inspection, as applicable. Corrective actions include, but are not


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation limited to, those outlined in the O & M Plan for the ESP. The Permittee shall keep a record of the type and date of any corrective action taken for the ESP. [40 CFR 64.7(6), Minn. R. 7017.0200]

5.51.7 If the Permittee replaces TREA 5, the replacement control must meet or exceed the control efficiency requirements of TREA 5 as well as comply with all other requirements of TREA 5. Prior to making such a change, the Permittee shall apply for and obtain the appropriate permit amendment, as applicable. If no amendment is needed for the replacement, the Permittee shall submit an electronic notice to the Agency using Form CR-05. The notice must be received by the Agency seven working days prior to the commencement/start of replacement. [40 CFR 64.7, Title I Condition: 40 CFR pt. 52, 21(j)(BACT) & Minn. R. 7007.3000]

5.51.8 Documentation of Need for Improved Monitoring: If the Permittee fails to achieve compliance with an emission limitation or standard for which the monitoring did not provide an indication of an excursion or exceedance while providing valid data, or the results of compliance or performance testing document a need to modify the existing pressure drop range, the Permittee shall promptly notify the MPCA and, if necessary, submit a permit amendment application to address the necessary monitoring change. [40 CFR 64.7(e), Minn. R. 7017.0200]


5.51.10 The Permittee shall maintain records of monitoring data, monitor performance data, corrective actions taken, and other supporting information required to be maintained. The Permittee may maintain records on alternative media, such as microfilm, computer files, magnetic tape disks, or microfiche, provided that the use of such alternative media allows for expeditious inspection and review, and does not conflict with other applicable recordkeeping requirements. [40 CFR 64.9(b), Minn. R. 7017.0200]


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation 5.51.11 The Permittee shall operate and maintain the

electrostatic precipitator (ESP) in accordance with the Operation and Maintenance (O & M) Plan. The Permittee shall keep copies of the O & M Plan available onsite for use by staff and MPCA staff. [Minn. R. 7007.0800, subp. 14]

5.51.12 Monitoring Equipment: The necessary monitoring equipment must be installed, in use, and properly maintained, including maintaining the necessary parts for routine repairs of the monitoring equipment, whenever operation of the monitored control equipment is required. [40 CFR 64.7(b), Minn. R. 7017.0200]

5.51.13 Periodic Inspections: At least once per calendar quarter, or more frequently if required by the manufacturer, the Permittee shall inspect the control equipment components that are subject to wear or plugging, for example: bearings, belts, hoses, fans, nozzles, orifices, and ducts. The Permittee shall maintain a written record of the inspection and any corrective actions taken resulting from the inspection. [40 CFR 64.3, Minn. R. 7017.0200]

TREA 12 CE220 Wet Scrubber -

Cl02 Generator

5.52.1 The Permittee shall operate and maintain the scrubber in accordance with the Operation and Maintenance (O & M) Plan. The Permittee shall keep copies of the O & M Plan available for use by staff and MPCA staff. [Minn. R. 7007.0800, subp. 14]

5.52.2 Pressure Drop >= 3.2 inches of water column 3-hour block average (this is pressure drop of the gas stream), unless a new range is set pursuant to Minn. R. 7017.2025, subp. 3, based on the values recorded during the most recent MPCA-approved performance test where compliance was demonstrated. The new range shall be implemented upon receipt of the Notice of Compliance letter granting preliminary approval. The range is final upon issuance of a permit amendment incorporating the change. [Minn. R. 7007.0800, subp. 14]

5.52.3 Liquid Flow Rate >= 95.7 gallons per minute 3-hour block average, unless a new range is set pursuant to Minn. R. 7017.2025, subp. 3, based on the values recorded during the most recent MPCA-approved performance test where compliance was demonstrated. The new range shall be implemented upon receipt of the Notice of Compliance letter granting preliminary approval. The range is final upon issuance of a permit amendment incorporating the change.


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation (this is scrubbing liquid supply flow rate). [Minn. R. 7007.0800, subp. 14]

5.52.4 Pressure Drop Recordkeeping: Observe and record, once per operating shift, the pressure drop of the gas stream for TREA 12. [Minn. R. 7007.0800, subp. 14, Minn. R. 7007.0800, subp. 5]

5.52.5 Monitoring Equipment: (EQUI 82) The Permittee shall maintain the necessary monitoring equipment for measuring and recording liquid supply flow rate as required by this permit. The Permittee shall continuously monitor the liquid supply flow rate for TREA 12. [Minn. R. 7007.0800, subp. 14, Minn. R. 7007.0800, subp. 4]

5.52.6 The Permittee shall maintain records of monitoring data, monitor performance data, corrective actions taken, and other supporting information required to be maintained. The Permittee may maintain records on alternative media, provided that the use of such alternative media allows for expeditious inspection and review, and does not conflict with other applicable recordkeeping requirements. [Minn. R. 7007.0800, subp. 14, Minn. R. 7007.0800, subps. 4-5]

5.52.7 Corrective Actions: The Permittee shall take corrective action as soon as possible if any of the following occur: - the recorded pressure drop is outside the required operating range; or - the recorded liquid supply flow rate is outside the required operating range; or - the scrubber or any of its components are found during the inspections to need repair. Corrective actions shall return the pressure drop and/or liquid flow rate to within the permitted range, and/or include completion of necessary repairs identified during the inspection, as applicable. Corrective actions include, but are not limited to, those outlined in the O & M Plan for the scrubber. The Permittee shall keep a record of the type and date of any corrective action taken for the scrubber. [Minn. R. 7007.0800, subp. 14, Minn. R. 7007.0800, subp. 5]

TREA 13 CE240 Wet Scrubber -

Bleach Plant

5.53.1 Scrubber Parameter Values: To establish or reestablish the value for each operating parameter required to be monitored under 40 CFR Section 63.453, the Permittee shall use the procedures described in 40 CFR Section 63.453(n). [40 CFR 63.453(n), Minn. R. 7011.7700]

5.53.2 pH >= 11.4 (no units) 3-hour average of the gas scrubber (TREA 13) effluent. [40 CFR 63.453(c)&(n)), Minn. R. 7007.0800, subp. 14, Minn. R. 7011.7700]


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation 5.53.3 Liquid Flow Rate >= 121 gallons per minute 3-hour block

average or as determined during the most recent performance test (this is gas scrubber liquid influent flow rate for TREA 13). [40 CFR 63.453(c)&(n)), Minn. R. 7007.0800, subp. 14, Minn. R. 7011.7700]

5.53.4 CMS for Scrubber: The Permittee shall install, calibrate, certify, operate, and maintain a continuous monitoring system (CMS) to measure the following parameters for the gas scrubber: (1) The pH or the oxidation/reduction potential of the gas scrubber effluent; (2) The gas scrubber vent gas inlet flow rate or gas scrubber fan operational status; and (3) The gas scrubber liquid influent flow rate. An option to the CMS requirement above, is to install, calibrate, certify, operate, and maintain a CMS to measure the chlorine outlet concentration of each gas scrubber used to comply with the bleaching system outlet concentration requirement specified in 40 CFR Section 63.445(c)(2). [40 CFR 63.453(a),(c),&(d), Minn. R. 7011.7700]

5.53.5 Corrective Actions: If the monitored parameter is out of the range as described above, the Permittee shall follow the facility O&M Plan and perform the necessary corrective action(s) as soon as possible to get the parameters back into the correct range. The Permittee shall keep a record of the type and date of all corrective actions taken. [Minn. R. 7007.0800, subp. 14, Minn. R. 7007.0800, subp. 5]


Scrubber - Lime Kiln

5.54.1 Install, calibrate, maintain, and operate a continuous parameter monitoring system (CPMS) that can be used to determine and record the pressure drop across the scrubber and the scrubbing liquid flow rate at least once every successive 15-minute period using the procedures in 63.8(c), as well as the procedures in paragraphs (e)(10)(i) and (ii). The owner or operator of each affected source or process unit that uses an ESP, wet scrubber, RTO, or fabric filter may monitor alternative control device operating parameters subject to prior written approval by the Administrator. [40 CFR 63.864(e)(10)&(13), 40 CFR 64.7(a), Minn. R. 7011.7700]

5.54.2 Install, calibrate, maintain, and operate a monitoring device for the continuous measurement (at least once


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation every 15 minutes) of the pressure loss of the gas stream through the control equipment. The monitoring device used for the continuous measurement of the pressure drop of the gas stream across the scrubber must be certified by the manufacturer to be accurate to within a gage pressure of +/-2 inches of water gage pressure. [40 CFR 60.284(b)(2)(i), 40 CFR 63.864(e), 40 CFR 64.7(a), Minn. R. 7011.2540]

5.54.3 Install, calibrate, maintain, and operate a monitoring device for the continuous measurement of the scrubbing liquid flow rate. The monitoring device used for continuous measurement of the scrubbing liquid flow rate must be certified by the manufacturer to be accurate within +/-5 percent of the design scrubbing liquid flow rate. [40 CFR 63.864(e), 40 CFR 64.7(a), Minn. R. 7011.7700]


5.54.5 Record once every 15 minutes as equally spaced intervals, or as an arithmetic or integrated three-hour block average, measurements obtained from the monitoring device for the continuous measurement of the pressure loss of the gas stream through the control equipment and from the monitoring device for the continuous measurement of the scrubbing liquid supply pressure to the control equipment. [40 CFR 60.284(c)(4), 40 CFR 63.864(a)(2), 40 CFR 63.864(e), 40 CFR 64.3(a), Minn. R. 7011.2459]

5.54.6 After completion of the Initial Performance test, the Permittee is in violation of the Subpart MM Standards of 40 CFR Section 63.862 if the Lime Kiln Scrubber accumulates 6 or more 3-hour operating parameter exceedances within any 6-month calendar reporting period. For purposes of determining the number of monitoring exceedances, no more than one exceedance shall be attributed in any given 24-hour period. [40 CFR 63.864(k)(2)(iii), 40 CFR 63.864(k)(3)]

5.54.7 Corrective Actions: If the monitored parameter is out of the range as described above, the Permittee shall follow the facility O&M Plan and the SSMP and perform the necessary corrective action(s) as soon as possible to get the parameters back into the correct range. The Permittee shall keep a record of the type and date of all


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation corrective actions taken. [40 CFR 63.864(k), Minn. R. 7007.0800, subp. 14, Minn. R. 7007.0800, subp. 5]

5.54.8 On-going compliance provisions. Lime kiln units are required to implement corrective action, when any 3-hour average parameter value is outside the range of values established in paragraph (j) of this section. [40 CFR 63.864(k)(1)(ii), Minn. R. 7011.7700]

5.54.9 SSM Excess Emissions Report: Report any/all excess emissions quarterly within 30 days following the end of the calendar quarter. The report must contain the required elements specified in 40 CFR Section 63.10(c). Reporting excess emissions below the violation thresholds of 63.864(k) does not constitute a violation of the Subpart MM standard. When no excess emissions have occurred, the Permittee shall submit a semi-annual report stating that no excess emissions have occurred during the reporting period. Subpart MM excess emission reports may be combined with Subpart S semi-annual excess emission reports. [40 CFR 63.867(c), Minn. R. 7011.7700]

5.54.10 The Permittee shall vent emissions from EQUI 13 to TREA 15 whenever EQUI 13 operates, and operate and maintain TREA 15 at all times that any emissions are vented to TREA 15 . The Permittee shall document periods of non-operation of the control equipment TREA 15 whenever EQUI 13 is operating. [Minn. R. 7007.0800, subp. 14, Minn. R. 7007.0800, subp. 2]

5.54.11 Water pressure >= 302 psi (gauge) 3-hour block average, unless a new range is set pursuant to Minn. R. 7017.2025, subp. 3 based on the values recorded during the most recent MPCA-approved performance test where compliance was demonstrated. The new range shall be implemented upon receipt of the Notice of Compliance letter granting preliminary approval. The range is final upon issuance of a permit amendment incorporating the change. This pressure is the scrubber liquid supply pressure (at nozzle). (EPA letter dated 12/8/04 allowing this under 40 CFR Section 63.864(j)(2) and (3) (ADI Control Number M050014)). [40 CFR 63.864(j)(2)&(3), 40 CFR 64.3(a), Minn. R. 7017.2025, subp. 3]

5.54.12 Liquid Flow Rate >= 403 gallons per minute 3-hour block average, unless a new limit is set pursuant to Minn. R. 7017.2025, subp. 3, based on the values recorded during the most recent MPCA-approved performance test where compliance was demonstrated. The new limit shall be implemented upon receipt of the Notice of Compliance letter granting preliminary approval. The limit is final upon issuance of a permit amendment incorporating the change.


Subject Item Sec. SI.Regt SI des:SI desc Requirement & Citation (EPA letter dated 12/8/04 allowing this under 40 CFR Section 63.864(j)(2) and (3) (ADI Control Number M050014)). [40 CFR 63.864(j)(2)&(3), 40 CFR 64.3(a), Minn. R. 7017.2025, subp. 3]

5.54.13 If the Permittee replaces TREA 15, the replacement control must meet or exceed the control efficiency requirements of TREA 15 as well as comply with all other requirements of TREA 15. Prior to making such a change, the Permittee shall apply for and obtain the appropriate permit amendment, as applicable. If no amendment is needed for the replacement, the Permittee shall submit an electronic notice to the Agency using Form CR-05. The notice must be received by the Agency seven working days prior to the commencement/start of replacement. [40 CFR 64.7, Title I Condition: 40 CFR 52.21(b)(2)(i)(netting) & MInn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]




5.54.17 The Permittee shall calibrate the gauges at least once every 12 months and shall maintain a written record of any action resulting from the calibration. [40 CFR 64.3, Minn. R. 7017.0200]


6. Submittal/action requirements

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

Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation TFAC 5 07100002 Boise White

Paper LLC - Intl Falls

6.1.1 Reporting: The Permittee shall submit a report : Due annually, by the 30th of January, of the previous 12 monthly 12-month rolling average calculations of the black liquor solids (virgin bone dried basis) production. [Minn. R. 7007.0800, subp. 6]

6.1.2 PM < 10 micron : The Permittee shall submit a computer dispersion modeling protocol : Due 1461 calendar days after Permit Issuance Date. This protocol will describe the proposed modeling methodology and input data, in accordance with MPCA modeling guidance for Title V air dispersion modeling analyses. The protocol will be based on projected operating conditions under the next permit term. [Minn. R. 7007.0100, Minn. R. 7007.0800, subp. 2, Minn. R. 7009.0020, Minn. Stat. 116.07, subd. 4a, Minn. Stat. 116.07, subd. 9]

6.1.3 PM < 10 micron : The Permittee shall submit computer dispersion modeling results : Due 1826 calendar days after Permit Issuance Date. [Minn. R. 7007.0100, Minn. R. 7007.0800, subp. 2, Minn. R. 7009.0020, Minn. Stat. 116.07, subd. 4a, Minn. Stat. 116.07, subd. 9]

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

6.1.5 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


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation deviations have occurred, the Permittee shall submit the report stating no deviations. [Minn. R. 7007.0800, subp. 6(A)(2)]

6.1.6 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)]

6.1.7 EER: 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), Minn. R. 7007.1075, Minn. R. 7017.1110, subps. 1-2]

COMG 6 GP340 LVHC NCG


6.2.1 Report: The Permittee shall submit a report : Due annually, by the 30th of January starting 10/13/2010, a report of the previous 12 monthly 12-month rolling sum calculations of NCG (LVHC) oxidized in Boiler #1 and #2 and of NCG (LVHC) venting. [Minn. R. 7007.0800, subp. 6]

COMG 7 GP421 Kraft Pulping

Process Condensates

6.3.1 HAPs - Total (measured as Methanol) : The Permittee shall conduct a performance test : Due before 12/31/2018 every 60 months to show 92% (or 10.2 pounds per ton of ODP) destruction of HAPs and to establish the minimum MLVSS that will be used to show continuous compliance, using methods outlined in 40 CFR Part 63, Appendix C. 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. 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:


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

COMG 12 GP430 Bleach Plant 6.4.1 HAPs - Total : The Permittee shall conduct a

performance test : Due before 07/22/2020 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 26A, 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. [40 CFR 63.457(a)(2), Minn. R. 7011.7700]

COMG 13 GP431 40 CFR pt. 63,

subp. DDDDD Requirements

6.5.1 Compliance Report: submit a compliance status report : Due annually, by the 31st of January The Permittee shall submit an annual compliance report starting 1/31/2016. Each subsequent compliance report must cover the applicable 1-year period from January 1 to December 31. Annual compliance reports must be postmarked or submitted no later than January 31. [40 CFR 63.7550(b), 40 CFR 63.7550(a), Table 9]

COMG 15 GP433 40 CFR pt. 63,

subp. MM Requirements


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 6.6.1 Excess Emissions Report: The Permittee shall submit

excess emission/downtime report : Due semiannually at least. The Permittee must report any/all excess emissions quarterly within 30 days following the end of the calendar quarter if measured parameters meet any of the conditions specified in paragraph (k)(1) or (2) of 40 CFR Section 63.864. The report must contain the required elements specified in 40 CFR Section 63.10(c). Reporting excess emissions below the violation thresholds of 40 CFR Section 63.864(k) does not constitute a violation of the Subpart MM standard. When no excess emissions have occurred, the Permittee shall submit a semi-annual report stating that no excess emissions have occurred during the reporting period. Subpart MM excess emission reports may be combined with Subpart S semi-annual excess emission reports. [40 CFR 63.867(c), Minn. R. 7007.0800, subp. 5, Minn. R. 7011.7700]

EQUI 9 EU320 Recovery

Furnace -Furnace

6.7.1 Particulate Matter : The Permittee shall conduct a performance test : Due before 09/13/2021 every 60 months to measure emissions. Testing is due by the end of each 60 month period following the initial performance test date. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp. 8, using EPA Reference Methods 5 and 202, 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. [40 CFR 63.865(b)(1), Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(j)(BACT ) & Minn. R. 7007.3000]

6.7.2 PM < 10 micron : The Permittee shall conduct a performance test : Due before 09/13/2021 every 60 months to measure emissions. Testing is due by the end of each 60 month period following the initial performance test date. The performance test shall be conducted at worst case conditions as defined at Minn.


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation R. 7017.2005, subp. 8, using EPA Reference Method 201A and 202, 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. [40 CFR 63.865(b)(1), Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(j)(BACT ) & Minn. R. 7007.3000]

6.7.3 Sulfur Dioxide : The Permittee shall conduct an initial performance test : Due 365 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]

6.7.4 Volatile Organic Compounds : The Permittee shall conduct an initial performance test : Due 1826 calendar days after Permit Issuance Date to measure emissions, measured as carbon, excluding methane. 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]

6.7.5 Sulfur Dioxide: The Permittee shall submit a test frequency plan : Due 60 calendar days after Initial Performance Test Date for Sulfur Dioxide. 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]

6.7.6 Volatile Organic Compounds: The Permittee shall submit a test frequency plan : Due 60 calendar days after Initial Performance Test Date for VOC emissions.


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

EQUI 12 EU902 Paint Spray

Booth - Spray Booth/Coating Line

6.8.1 Reporting: The Permittee shall submit an annual report : Due annually, by the 30th of January for the previous 12 monthly 12-month rolling sum calculations of spray booth operation. [Minn. R. 7007.0800, subp. 6]

EQUI 13 EU340 Lime Kiln - Kiln 6.9.1 Particulate Matter : The Permittee shall conduct a

performance test : Due before 11/06/2017 every 36 months to measure emissions. Testing is due by the end of each 60 month period following the initial performance test date. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp. 8, using EPA Reference Methods 5 and 202, 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. [40 CFR 63.865, Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

6.9.2 PM < 10 micron : The Permittee shall conduct a performance test : Due before 11/06/2017 every 36 months to measure emissions. Testing is due by the end of each 36 month period following the initial performance test date. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp. 8, using EPA Reference Methods 210A and 202 or other method approved by MPCA in


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 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. [40 CFR 63.865, Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

6.9.3 Nitrogen Oxides : The Permittee shall conduct a performance test : Due before 09/05/2017 every 60 months to measure emissions. Testing is due by the end of each 60 month period following the initial performance test date. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp. 8, 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]

6.9.4 Sulfur Dioxide : The Permittee shall conduct a performance test : Due before 09/05/2017 every 60 months to measure emissions. Testing is due by the end of each 60 month period following the initial performance test date. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp. 8, using EPA Reference Method 6C, 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


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 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(k)(modeling) & Minn. R. 7007.3000]

6.9.5 Volatile Organic Compounds : The Permittee shall conduct a performance test : Due after 09/05/2017 every 60 months to measure emissions. Testing is due by the end of each 60 month period following the initial performance test date. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp. 8, using EPA Reference Methods 25A/18, 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]

6.9.6 Carbon Monoxide : The Permittee shall conduct a performance test : Due after 09/05/2017 every 60 months to measure emissions. Testing is due by the end of each 60 month period following the initial performance test date. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp. 8, 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


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

EQUI 16 EU430 Boiler #2 - Boiler 6.10.1 The Permittee shall submit a performance test plan :

Due 30 calendar days before Performance Test Date (Alternative Biomass Fuel Emission Testing submittal) of the operational and emission testing of a biomass fuel (emission testing will be conducted only if operational testing has been proven feasible), the permitee shall submit a written performance test notification and test plan. The test plan shall include (1) the type(s) and estimated amount of biomass to be tested, (2) operating parameters and anticipated fuel mixes during the emission testing of the boiler to be tested, (3) air pollutants that will be monitored (ie., PM, PM-10, and VOC), and (4) a testing schedule. [Minn. R. 7017.2018, Minn. R. 7017.2030, subps. 1-4]

6.10.2 Front-half Particulate Matter : The Permittee shall conduct performance test : Due 07/07/2019 every 36 months (rule states every third year). The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp. 8, using EPA Reference Method 5. Annual performance tests must be completed no more than 13 months after the previous performance test, unless the performance test results are less than 75 percent of the limit for 2 consecutive years, then each performance test must be conducted no more than 37 months after the previous performance test. [40 CFR 63.7515(a), Minn. R. 7011.7050]

6.10.3 Hydrochloric acid : The Permittee shall conduct performance test : Due 07/07/2019 every 36 months (rule states every third year). The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp. 8, using EPA Reference Method 26A. Annual performance tests must be completed no more than 13 months after the previous performance test, unless the performance test results are less than 75 percent of the limit for 2 consecutive years, then each performance test must be conducted no more than 37 months after the previous performance test. [40 CFR 63.7515(a), Minn. R. 7011.7050]

6.10.4 Mercury : The Permittee shall conduct performance test : Due 07/07/2019 every 36 months (rules states every third year). The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp. 8, using EPA Reference Methods


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 29 or 30B. Annual performance tests must be completed no more than 13 months after the previous performance test, unless the performance test results are less than 75 percent of the limit for 2 consecutive years, then each performance test must be conducted no more than 37 months after the previous performance test. [40 CFR 63.7515(a), Minn. R. 7011.7050]

6.10.5 Particulate Matter : The Permittee shall conduct a performance test : Due before 08/08/2020 every 60 months to measure emissions. Testing is due by the end of each 60 month period following the initial performance test date. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp. 8, using EPA Reference Methods 5 and 202, 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]

6.10.6 PM < 10 micron : The Permittee shall conduct a performance test : Due before 08/08/2020 every 60 months to measure emissions. Testing is due by the end of each 60 month period following the initial performance test date. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp. 8, using EPA Reference Method 201A and 202, 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


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation date. [Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

6.10.7 Volatile Organic Compounds : The Permittee shall conduct a performance test : Due before 08/08/2020 every 60 months to measure emissions. Testing is due by the end of each 60 month period following the initial performance test date. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp. 8, using EPA Reference Method 25A, 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]

6.10.8 The Permittee shall submit a compliance status report : Due by 31 days after end of each calendar half-year according to 40 CFR Section 63.7550(h). The Compliance Status Reports must cover the applicable semiannual reporting period from January 1 through June 30 or the semiannual reporting period from July 1 through December 31. The Compliance Status Report must be postmarked or submitted no later than July 31 or January 31, whichever date is the first date following the end of the semiannual reporting period. The Compliance Status Report must contain the information specified in 40 CFR Section 63.7550(c). [40 CFR 63.7550(b)(3) & (4), 40 CFR pt. 63, subp. DDDDD(Table 9), Minn. R. 7011.7050]

EQUI 17 EU440 Boiler #3 - Boiler 6.11.1 Annual Report: The Permittee shall submit an annual

report : Due annually, by the 30th of January starting 10/13/2010 . A report of the previous 12 monthly 12-month rolling average calculations for the annual capacity factor shall be submitted. [Minn. R. 7007.0800, subp. 2]

6.11.2 Carbon Monoxide : The Permittee shall conduct a performance test : Due before 08/08/2020 every 60 months to measure emissions. Testing is due by the end of each 60 month period following the initial


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation performance test date. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp. 8, 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]


EQUI 18 EU460 Boiler #9 - Boiler 6.12.1 Annual Report: The Permittee shall submit an annual

report : Due annually, by the 30th of January starting 10/13/2010 . A report of the previous 12 monthly 12-month rolling average calculations for the annual capacity factor shall be submitted. [Minn. R. 7007.0800, subp. 2]

6.12.2 Carbon Monoxide : The Permittee shall conduct a


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation performance test : Due before 08/08/2020 every 60 months to measure emissions. Testing is due by the end of each 60 month period following the initial performance test date. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp. 8, 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, Title I Condition: 40 CFR 52.21(k)(modeling)]


EQUI 25 EU909 Off-Machine

Coater - Other Emission Unit

6.13.1 Compliance Status Report: The Permittee shall submit


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation a compliance status report : Due semiannually, by the 30th of January and July starting 10/13/2010, including, at a minimum, the following information: 1) Company name and address; 2) A statement by a responsible official with that official's name, title, and signature certifying the accuracy of the content of the report; 3) Date of report and beginning and ending dates of the reporting period; 4) If there are no deviations from any emission limitations (emission limit or operating limit) that apply to you, a statement that there were no deviations from the emission limitations during the reporting period, and that no CMS was inoperative, inactive, malfunctioning, out-of-control, repaired, or adjusted; and 5) For each deviation from an emission limitation (emission limit or operating limit) that applies to you, the information listed in 40 CFR Section 63.3400(c)(2)(v)(A)-(C). [40 CFR 63.3400(c), Minn. R. 7011.7385]

EQUI 78 MR916 Lime Kiln TRS


6.14.1 The Permittee shall conduct CEMS cylinder gas audit (CGA) : Due semiannually (end of every second QA operating quarter in which there are at least 168 unit operating hours) except that a CGA is not required during any quarter in which a RATA was performed. The initial CGA must be performed within 180 days following certification of the CEMS. The CGAs shall be conducted according to the procedures outlined in Minn. R. 7017.1170, subp 4a(A). If the monitored emission unit is not in operation on the CGA due date, the owner or operator has a grace period of 168 operating hours to perform the CGA. [Minn. R. 7017.1170, subp. 4a]

6.14.2 The Permittee shall conduct a relative accuracy test audit : Due annually (end of every fourth QA operating quarter). RATAs shall be conducted and frequency may be reduced according to the procedures outlined in Minn. R. 7017.1170, subp. 5a. If the monitored emission unit is not in operation on the RATA due date, the owner or operator has a grace period of 720 operating hours to perform the RATA. [Minn. R. 7017.1170, subp. 5a]


Furnace Opacity COM - Continuous Opacity Monitor


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 6.15.1 The Permittee shall conduct COMS calibration error

audit : Due quarterly according to Procedure 3 of 40 CFR Pt. 60, Appendix F. Quarterly performance audits will include: optical alignment, calibration error, and zero compensation. Sources that achieve quality assured data for four consecutive quarters may reduce audit frequency to semi-annually. If an audit is failed, the source must resume quarterly audits to demonstrate performance again for four consecutive quarters. [Minn. R. 7017.1215]

EQUI 80 MR432 Boiler 2 Opacity


6.16.1 The Permittee shall conduct COMS calibration error audit : Due quarterly according to Procedure 3 of 40 CFR Pt. 60, Appendix F. Quarterly performance audits will include: optical alignment, calibration error, and zero compensation. Sources that achieve quality assured data for four consecutive quarters may reduce audit frequency to semi-annually. If an audit is failed, the source must resume quarterly audits to demonstrate performance again for four consecutive quarters. [Minn. R. 7017.1215]


Furnace NOx CEM - Continuous Emission Monitor


6.17.2 The Permittee shall conduct a relative accuracy test audit : Due annually (end of every fourth QA operating quarter). RATAs shall be conducted and frequency may be reduced according to the procedures outlined in Minn. R. 7017.1170, subp. 5a. If the monitored emission unit is not in operation on the RATA due date,


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation the owner or operator has a grace period of 720 operating hours to perform the RATA. [Minn. R. 7017.1170, subp. 5a]


Furnace TRS CEM - Continuous Emission Monitor




Furnace CO CEM - Continuous Emission Monitor


6.19.2 The Permittee shall conduct a relative accuracy test audit : Due annually (end of every fourth QA operating


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation quarter). RATAs shall be conducted and frequency may be reduced according to the procedures outlined in Minn. R. 7017.1170, subp. 5a. If the monitored emission unit is not in operation on the RATA due date, the owner or operator has a grace period of 720 operating hours to perform the RATA. [Minn. R. 7017.1170, subp. 5a]

EQUI 90 MR915 Boiler 2 CO CEM -

Continuous Emission Monitor

6.20.1 The Permittee shall conduct CEMS cylinder gas audit (CGA) : Due by the end of each three of four calendar quarters 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 63.7525(a), Minn. R. 7017.1170, subp. 4a]

6.20.2 The Permittee shall conduct a relative accuracy test audit : Due one of each four calendar quarters. [40 CFR 63.7525(a), Minn. R. 7017.1170, subp. 5a]

EQUI 109 MR421 Boiler 1 O2 CEM -




EQUI 110 MR420 Boiler 1 NOx CEM

- Continuous Emission Monitor


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 6.22.1 The Permittee shall conduct CEMS cylinder gas audit

(CGA) : Due semiannually (end of every second QA operating quarter in which there are at least 168 unit operating hours) except that a CGA is not required during any quarter in which a RATA was performed. The initial CGA must be performed within 180 days following certification of the CEMS. The CGAs shall be conducted according to the procedures outlined in Minn. R. 7017.1170, subp 4a(A). If the monitored emission unit is not in operation on the CGA due date, the owner or operator has a grace period of 168 operating hours to perform the CGA. [Minn. R. 7017.1170, subp. 4a]




6.23.1 The Permittee shall conduct a cylinder gas audit : Due by the end of each three of four calendar quarters 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, 5.1.2, Minn. R. 7017.1170, subp. 4]

6.23.2 The Permittee shall conduct a relative accuracy test audit : Due one of each four calendar quarters. [40 CFR pt. 60, Appendix F, 5.1.1]


Furnace O2 CEM - Continuous Emission Monitor

6.24.1 The Permittee shall conduct CEMS cylinder gas audit (CGA) : Due semiannually (end of every second QA operating quarter in which there are at least 168 unit operating hours) except that a CGA is not required during any quarter in which a RATA was performed. The initial CGA must be performed within 180 days following certification of the CEMS. The CGAs shall be conducted according to the procedures outlined in Minn. R. 7017.1170, subp 4a(A). If the monitored emission unit is not in operation on the CGA due date,


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation the owner or operator has a grace period of 168 operating hours to perform the CGA. [Minn. R. 7017.1170, subp. 4a]


EQUI 125 MR327 Lime Kiln O2 CEM

- Continuous Emission Monitor





6.26.1 The Permittee shall conduct a cylinder gas audit : Due by the end of each three of four calendar quarters 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, 5.1.2, Minn. R. 7017.1170, subp. 4]

6.26.2 The Permittee shall conduct a relative accuracy test


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation audit : Due one of each four calendar quarters. [40 CFR pt. 60, Appendix F, 5.1.1]



6.27.1 The Permittee shall conduct CEMS cylinder gas audit (CGA) : Due by the end of each three of four calendar quarters 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 63.7525(a), Minn. R. 7017.1170, subp. 4a]

6.27.2 The Permittee shall conduct a relative accuracy test audit : Due one of each four calendar quarters. [40 CFR 63.7525(a), Minn. R. 7017.1170, subp. 5a]







6.29.1 The Permittee shall conduct CEMS cylinder gas audit (CGA) : Due semiannually (end of every second QA operating quarter in which there are at least 168 unit


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation operating hours) except that a CGA is not required during any quarter in which a RATA was performed. The initial CGA must be performed within 180 days following certification of the CEMS. The CGAs shall be conducted according to the procedures outlined in Minn. R. 7017.1170, subp 4a(A). If the monitored emission unit is not in operation on the CGA due date, the owner or operator has a grace period of 168 operating hours to perform the CGA. [Minn. R. 7017.1170, subp. 4a]


EQUI 940 EU917 Intermediate

Chip Cyclone

6.30.1 PM < 10 micron : The Permittee shall conduct an initial performance test : Due 2556 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, 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]

6.30.2 Particulate Matter : The Permittee shall conduct an initial performance test : Due 2556 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 Methods 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]

6.30.3 PM < 10 micron: The Permittee shall submit a test frequency plan : Due 60 calendar days after Initial Performance Test Date for PM < 10 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.


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 7007.3000]

6.30.4 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]

EQUI 944 EU602 Wastewater

Treatment Plant Cooling Tower

6.31.1 Reporting: The Permittee shall submit an annual report : Due annually, by the 30th of January for the previous 12 monthly 12-month rolling sum calculations of wastewater throughput. [Minn. R. 7007.0800, supb. 6]

EQUI 945 EU322 Smelt Dissolving

Tank


6.32.2 Nitrous Oxide : The Permittee shall conduct an initial performance test : Due 365 calendar days after Permit Issuance Date to measure emissions and develop an emission factor. 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. [Minn. R. 7007.3000, Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(o)]

6.32.3 Sulfur - Total Reduced including H2S : The Permittee shall conduct a performance test : Due before 09/12/2021 every 60 months to measure emissions. Testing is due by the end of each 60 month period following the initial performance test date. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp. 8,


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation using EPA Reference Method 16 A/C, 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]

6.32.4 PM < 10 micron : The Permittee shall conduct a performance test : Due before 09/12/2021 every 60 months to measure emissions. Testing is due by the end of each 60 month period following the initial performance test date. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp. 8, using EPA Reference Methods 5 and 202, 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. [40 CFR 63.865(b)(1), Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

6.32.5 Particulate Matter : The Permittee shall conduct a performance test : Due before 09/12/2021 every 60 months to measure Total Particulate Matter. Testing is due by the end of each 60 month period following the initial performance test date. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp. 8, using EPA Reference Methods 5 and 202, or other method approved by MPCA in the performance test plan approval. Testing conducted during the 60 days prior to the


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 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. [40 CFR 63.865(b)(1), Minn. R. 7017.2020, subp. 1, Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

6.32.6 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]

6.32.7 Nitrogen Oxides: The Permittee shall submit a test frequency plan : Due 60 calendar days after Initial Performance Test Date for NOx 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(o)(visibility) & Minn. R. 7007.3000]

EQUI 949 Boiler 2 NOX &

SO2 CEM


6.33.2 The Permittee shall conduct a relative accuracy test audit : Due annually (end of every fourth QA operating


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation quarter). RATAs shall be conducted and frequency may be reduced according to the procedures outlined in Minn. R. 7017.1170, subp. 5a. If the monitored emission unit is not in operation on the RATA due date, the owner or operator has a grace period of 720 operating hours to perform the RATA. [Minn. R. 7017.1170, subp. 5a]

STRU 20 SV173 Brown Stock

Decker

6.34.1 Sulfur Dioxide : The Permittee shall conduct an initial performance test : Due 365 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]


6.34.3 Sulfur - Total Reduced including H2S : The Permittee shall conduct an initial performance test : Due 365 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 16A/C, 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]

6.34.4 Sulfur Dioxide: The Permittee shall submit a test frequency plan : 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]


Subject Item Sec.SI.Reqt SI des:SI desc Requirement & Citation 6.34.5 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]

6.34.6 Sulfur - Total Reduced including H2S: The Permittee shall submit a test frequency plan : Due 60 calendar days after Initial Performance Test Date for TRS 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]


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(A)

Fuel Use: space heaters fueled by kerosene, natural gas, or propane, less than 420,000 Btu/hr -Natural Gas Air Heater (200,000 BTU/hr) -Unit Heater #1 (200,000 BTU/hr) -Unit Heater #2 (200,000 BTU/hr) -NG-Fired Space Heaters (#1 PM) (160,000 BTU/hr) -Warehouse Space Heaters (BM) (75,000 BTU/hr) -Chipper Building Space Heaters (75,000 BTU/hr) -M, D & W Space Heaters #2 (93,000 BTU/hr) -Natural Gas Heater Unit #1 (93,000 BTU/hr) -Natural Gas Heater Units (4) #2 (160,000 BTU/hr) -Natural Gas Heater Units (4) #3 (65,000 BTU/hr)

PM <= 0.60 or 0.40 lb/MMBtu, depending on year constructed Opacity <= 20% with exceptions (Minn. R. 7011.0510 or Minn. R. 7011.0515)

Minn. R. 7007.1300, subp. 3(B)(1)

Infrared electric ovens

-Lead dryer

Opacity <= 20% (Minn. R. 7011.0105)

Minn. R. 7007.1300, subp. 3(G)

Emissions from a laboratory, as defined in Minn. R. 7007.1300, subp. 3(G) -Lab– Bldg. 31 -Laboratory Bldg. 10 -Laboratory 1 - Filter Plant -Laboratory 2 - Filter Plant -Laboratory - O2 Plant -Laboratory - Bldg. 30 -Laboratory - Bldg. 4 -Laboratory - Testing Area (BM) Bldg. 4

PM, variable depending on airflow Opacity <= 20% (Minn. R. 7011.0710 or Minn. R. 7011.0715, depending on the year operation began)

Minn. R. 7007.1300, subp. 3(H)(3)

Brazing, soldering or welding equipment -Welding - Bldg. 30 -Contractor Welding Areas (3) -Soldering - Instrument Shop -Welding #7 -Welding #1 -Welding #2 -Welding #3 -Welding #6 -Welding #9 -Welding areas (2) #4 -Welding areas (3) #5 -Welding areas (4) #10 -Welding areas (4) #8



Minn. R. Rule description of the activity General applicable requirement

-Welding Rod Oven Minn. R. 7007.1300, subp. 3(H)(4)

Blueprint copiers and photographic processes -Blueprint Machine 1 -Blueprint Machine 2

Opacity <= 20% (Minn. R. 7011.0105)

Minn. R. 7007.1300, subp. 3(I)

Individual units with potential emissions less than 2000 lb/year of certain pollutants (Units/activities listed in previous permits as fugitive sources that qualify as insignificant activities) -FS 001 Log Debarking -FS 002 Bark Conveying -FS 003 Bark Pile at Process Center -FS005 Bark Loader at Process Center -FS 008 Wood Chipping and Chip Conveying -FS 009-1 Wood Chip Pile -FS 009-2 Wood Chip Pile -FS 009-3 Wood Chip Pile -FS 009-4 Wood Chip Pile -FS 009-5 Wood Chip Pile -FS 009-6 Wood Chip Pile -FS 009-7 Wood Chip Pile -FS 010-1 Wood Chip Loader -FS 010-2 Wood Chip Loader -FS 010-3 Wood Chip Loader -FS 010-4 Wood Chip Loader -FS 010-5 Wood Chip Loader -FS 010-6 Wood Chip Loader -FS 010-7 Wood Chip Loader -FS 011 Purchased Chip Truck Dump -FS 012 Purchased Chip Conveying -FS 401 Hog Fuel Boiler Truck Dump -FS 402 Bark & Sludge Conveying -FS 603 WW Treatment Plant Secondary Clarifier #1 -FS 604 WW Treatment Plant Secondary Clarifier #2 -FS 701 Paved Roads at Mill


Minn. R. 7007.1300, subp. 4

Individual units with potential or actual emissions meeting the criteria in Minn. R. 7007.1300, subp. 4(A)-(D) -Alkaline Sewer -Bleached HW H/D Chest -Bleached SW H/D Chest -Bleached Trans. H/D Chest -Building Sewer -FF Decker Filtrate Tank -FF Decker Hood -Methanol Tank -Pre-wash Blend Chest -Pre-wash Filtrate Tank -Sulfuric Acid Tank & Unloading

Various requirements – these are allowed as insignificant activities because they have been listed since PA 001



-Ash Pit – outside bldg. 10 -Blow Down Tank -Blow Tank Overflow -Condensate Collection Tank -Flash Tank -Sewer U-drain - Bldg 10 -Sewer U-drain - Bldg. 11B -Sludge Pit (2 – Primary and Secondary) -4th Causticizer -Concentrated Acid Tank -Deaerator -Dilute Acid Tank -Dregs Drop Pt. From Conveyor to Mud Pit -Dregs Drop Pt. From Dregs Filt. to Conveyor -Dregs Filter Hood Exhaust -Dregs Precoat Filter Process -Dregs Surge Tank -Evaporator Condensate Flash Tank -Flexible Liquor Storage Tank (WL, GL, or BL) -Fresh Lime Silo -Lime Kiln Scrubber Clarifier -Lime Mud & Dregs Filter Vacuum Pumps -Lime Mud Drop Pt-Convey. to Mud Pit -Lime Mud Drop Pt-Lime Mud Filt to Conv. -Lime Mud Mix Tank -Lime Mud Pit -Lime Mud Precoat Filter Process -Lime Mud Storage Tank -Recovery Furnace Chemical Feed System -Sewer U-drain - Bldg. 20C -Soap Tank -Spill Collection Tanks -Weak Wash Tank -White Liquor Pressure Filter -White Liquor Storage -#1 Wood Chip Cyclone -#2 Wood Chip Cyclone -Digester Chip Fill Chutes -Dump Tanks (Screening Room) -Knot Tank & Knots Handling -No. 2 Washer Filtrate Tank -No. 3 Washer Filtrate Tank -No. 4 Washer Filtrate Tank -Pressure Screen Accepts Tanks -Pressure Screen Rejects Tanks -Primary Pressure Screen -Quatinary Pressure Screen -Riffle Screen -Secondary Pressure Screen -Talc Slurry Tank -Tertiary Pressure Screen



-Turpentine Storage Tank -U-Sewer Drain - Bldg. 21 -U-Sewer Drain - Bldg. 22A -U-Sewer Drain - Bldg. 24 -U-Sewer Drain - Bldg. 50 -U-Sewer Drain - Bldg. 51 -#2 Lift Station -#2 Lift Station Surge Tank -#8 Lift Station Defoamer Tank -Ammonia Tank for Filter Plant -Belt Presses (3) -Dry Polymer Drop -Filter Plant - Chemical Storage Tank -Foam Chamber -Insulite Clarifier -Main Sulfuric Acid Storage Tk. & Unloading -New Defoamer Tank -New Demin Acid Day Tank -No. 3 Lift Station -No. 8 LIft Station -O2 Plant Degreasing -Oil Accumulator Tank -Old Defoamer Tank -Old Woodroom Sanitary Lift Station -Refuse Disposal Site -Salt Drop -Screw Presses -Sludge Slurry Tank -Sodium Silicate Bldg. -Splitter Building -Sulfuric Acid Tank Outside -Treatment Plant Process Sewer U-drains -UNOX Vents (3) -Water Filtration Plant -#1 Sheeter Bldg. -#1 Size Press Base Mill Starch Silo -#1 Wet End Base Mill Starch Silo -#2 Size Press I-1 Starch Silo -#2 Wet End I-1 Starch Silo -#4 PM Natural Gas Dryer -A-mixer (BM) -Additive Area (#1 PM) -Additive Storage Area (#1 PM) -ASA Boilout Tank -ASA Storage Tank -B-mixer (BM) -Broke Thickener Feed Chest -Caustic Boilout Tank -Chemical Enclosure -Coater Broke Tank -Cooked Size Press Starch Tanks



-Cooked Wet End Starch Tank -Cooked Wet End Starch Tanks -Deaerator Vacuum (#1 PM) -Hardwood and Softwood Levelling Chests -Kady Mill Mix Tank -Machine Dump Chests -No. 1 PM Broke Storage Chest -No. 1 PM Machine Chest -No.2 PM Cycle Tanks (2) - HW & SW -No.3 PM Cycle Tanks (2) - HW & SW -No.4 PM Cycle Tanks (2) - HW & SW -Open Dye Tanks (6) (#1 PM) -Paper shredder (BM) -Retention Aid Mix Tank -Scripset Storage Tank -Scripset Tanks (2) (BM) -Sheeter Trim System (BM) -Solvent Drum Storage Areas (BM) -Starch Slurry -Stock Hydraulic Tanks (24) -Stock Preparation -Stock Tanks (6) -Stuff Box -Sulfuric Acid Tank #3 (BM) -U-Drain/Sewer Inside Bldg. -Upper White Water Chest -Various Parts Cleaning Compounds -Wet End Slurry Tank -Bark Hog -Blower Feed Screen #1 -Blower Feed Screen #2 -Blower Feed Screen #3 -Chipper Blowers (5) -Small Sawdust Piles -Blasting booth -Chemical Storage Area -Degasifier Vacuum -Degreaser - 1 -Degreaser - 14 -Degreaser - 19 -Degreaser - 2 -Degreaser - 29 -Degreaser - 3 -Degreaser - 4 -Degreaser - 6 -Degreasers - 12, 13 -Degreasers - 12, 13 -Degreasers - 4, 5 -Flanges, Pumps, Valves, etc. -Oven Dryer/Incinerator -Wood working machinery



APPENDIX B – Ambient TRS Plan Facility Name: Boise White Paper LLC - Intl Falls Permit Number: 07100002-014

AMBIENT MONITORING PLAN for

TOTAL REDUCED SULFUR (TRS)

COMPOUNDS

BOISE WHITE PAPER, LLC INTERNATIONAL FALLS, MINNESOTA FACILITY

October 29, 2009

Introduction


Boise White Paper, LLC (Boise) operates an integrated Kraft pulp and paper mill (mill) in International Falls, Minnesota. The mill manufactures a variety of coated and uncoated fine paper products. The facility consists of a wood-yard, chip processing center, pulp mill, bleach plant, chemical recovery system, power plant, wastewater treatment facility, industrial landfill, paper mill, finishing and sheeting operations, warehouse, and shipping facilities. The mill is immediately across the Rainy River from Fort Frances, Ontario and the Abitibi -Bowater (AB) Kraft mill and their waste water treatment lagoon system located north and northwest of the Boise mill.

Kraft pulp mill odors are primarily associated with total reduced sulfur (TRS) compounds generated in the pulping process. The predominate components of TRS compounds are hydrogen sulfide, methyl mercaptan, dimethyl sulfide, and dimethyl disulfide. TRS compounds have low odor thresholds; therefore, most people can smell TRS chemicals at extremely low levels, well below levels associated with health standards. Odor associated with the mill can be generally described in two ways. "Normal odor" is low level odor, or background odor, experienced during normal mill operations. "Episodic odor" is a stronger odor experienced for short periods due to temporary equipment or process problems. The TRS concentration guideline for this plan is 50 ppb for a 1-hour average. The mill's objective is to always operate below the guideline level. As a result, initial investigation begins when the average ambient TRS concentration is greater than 30 ppb.

The AB waste water treatment system has been identified as the predominate source of odor in the community the past few years, while both mills have made feasible improvements over the years to capture TRS odor compounds within the mills utilizing NCG systems and closed sewer systems. During 2008 and 2009 AB made progress in reducing TRS odor by preventing excessive odor from developing in the wastewater treatment system during normal operating periods. There have still been community odor incidents during infrequent maintenance activities. As a result of the AB process improvements, 2009 odor incidences have decreased compared to previous years as documented in quarterly TRS reports.

Also located within the mill boundary is a Precipitated Calcium Carbonate (PCC) plant owned by Specialty Minerals, LLC. This TRS source utilizes Boise Lime kiln and Boiler exhaust to sequester C02 and produce PCC, which is utilized as a paper filler, reducing the demand for wood pulp fiber. The gasses emitted from the PCC plant have gone through two caustic scrubbing systems and are anticipated to have negligible concentrations of hydrogen sulfide or methyl mercaptan components, as these components are readily scrubbed out of the air stream. These two TRS components present the highest health risks of the four TRS components, resulting in the health risks from this source to be mitigated, although some odor may remain. The organic TRS components are likely to still be mostly contained in the gas stream as they are not as readily removed by the caustic scrubbing process.

The proximity to other odor sources and immediate surrounding population, has made odor reduction a high priority. It has been a target tracked for improvement in the Boise ISO 14001 EMS. This updated document is Boise's newest effort in a long history of odor reducing projects. This updated plan is designed to monitor and facilitate reduction in TRS odors associated with the International Falls facility. The most recent TRS incident with a one-hour average greater than 50 ppb on the ambient TRS monitor and attributed to the Boise mill occurred November 14, 2008.

Major Boise TRS sources have been collected in the LVHC and HVLC NCG collection systems. Possible sources of TRS compounds from the mill are listed below. These sources include both point and fugitive sources.

LVHC NCG Sources Venting (Secondary Condenser, Turpentine Decanter, Digester Relief Condensers, Turpentine Pad Water Tank, Pre-Evaporator Hotwell, Stripper Feed Tank, and Evaporator Hotwell

);> HVLC NCG Collected Sources Venting (Brownstock Washers Foam System, #1 Filtrate Foam Breaker Tank, Heavy Black Liquor Tanks, Salt Cake Mix Tank, Sluice Bowl, Hopper Flush Tank, Rapid Drain Tank (collected in 2008));

);> Brownstock Decker );> Dirty Hot Water tank, );> Blow Heat Accumulator Overflow, );> Recovery Furnace (TRS CEM monitoring), );> Smelt Dissolving Tank, );> Lime Kiln (TRS CEM monitoring), );> 14% Liquor Tank, );> #9 & #10 Brownstock High Density Tanks,


);> 18% Liquor Tank, );> Green Liquor Clarifier Tank, );> Primary Clarifier (mitigated by closed sewer), );> Cooling Tower (mitigated by closed sewer), );> #3 Lift Station );> #8 Lift Station

Monitoring Program The guidance of this document is EXHIBIT M (Ambient Air Monitoring Procedures for Determination of Compliance), appendix B of the original Boise Cascade's Title V permit, permit number 07100002-001. However, since this monitor is for odor control and not for compliance of a state or federal ambient air quality standard, there may be minor discrepancies between the guidance document and this plan. The monitoring program consists of three phases;

1. Responsible operations control, 2. Ambient monitoring, and 3. Source investigation monitoring for TRS compounds.

These three elements will allow the facility to maintain minimum TRS emissions, monitor TRS levels in the vicinity of the mill, and identify and troubleshoot TRS emitting processes to further minimize emission rates.

Good operational control of aforementioned TRS sources will continue to provide the level of control necessary at the "Normal odor" level. The main causes of "Episodic odor" are disruptions in the state-of- the-art NCG collection systems. Good operating control of the NCG systems shall include proper maintenance of the system and a controlled, orderly, and safe shutdown of the system after an immediate investigation and determination that the problem is not readily correctable.

The ambient monitoring phase will include the TRS ambient monitoring station and met station located at the U.S. Customs & Immigration Border Crossing Station (US Customs). This station will be monitored and maintained by the mill. This monitoring will include instantaneous, 1-minute average and 1-hour average TRS concentration, wind direction, and wind speed. This data aids in determining TRS source location.

"Episodic odors" are attributable to the mill if there is a specific malfunction event at the mill and the wind direction is from the mill zone of influence where the event occurred. Due to local atmospheric influences, including two mills generating significant amounts of warm air, the Rainy River acting as a heat sink or source, and the topographies of the surrounding area, wind speed and direction are not necessarily indicative of the odors' source. The thermal uplift of the immediate area can pull air from many sources and from many different directions during calm wind conditions. "Episodic odors" and "Normal odors" are not attributable to the mill during the following conditions:


1) Wind Direction is beyond the Boise mill's influence of

a) U.S. Customs: 250°- 345° 2) Wind Speeds less than 2.5 mph (unless there is a specific malfunction at the mill and the wind direction is

from the mill zone of influence) 3) Wind directions between 320° and 345° are more likely from an offsite source if no attributable

onsite source can be located due to improvements made in the Boise sewer system.

The source investigation phase of the monitoring program will utilize plant personnel checking ambient conditions at locations within the mill boundaries. This will allow the mill to not only monitor ambient conditions, but also, determine which sources or process variables are contributing to the ambient TRS emissions. This three-phased approach to monitoring will benefit both the community and the mill by providing the ability to identify TRS sources and process variations that lead to elevated ambient TRS levels.

Monitoring Equipment Maintenance and Quality Control

The monitoring equipment is a Paragon ambient monitoring system that includes an S02 scrubber, a thermal oxidizer, an API Model 152 photo luminescent S02 analyzer (ranged 0-500 ppb) and a meteorological station consisting of wind speed and direction.

The ambient monitor system shall be maintained by the continuous emissions monitoring (CEM) electrical and instrumentation group. This will include the manufacturer s recommended maintenance as well as maintenance practices that we have developed with our CEMS.

The analyzer will be precision tested at zero and 20% of span at least once every fourteen days. A five-point calibration shall be performed at least once every quarter. The quarterly calibration will be performed at zero, 20% (100 ppb), 40% (200 ppb), 60% (300 ppb) and 80% (400 ppb) of span. The calibration and precision checks must be within+/- 15% of the standard used. For example, when calibrating for the data to be considered valid:

the 100 ppb calibration result must be between 85 ppb and 115 ppb; the 200 ppb calibration result must be between 170 ppb and 230 ppb; the 300 ppb calibration result must be between 255 ppb and 345 ppb; and the 400 ppb calibration result must be between 340 ppb and 460 ppb.

Maintenance corrective action and recalibration will be taken if the meter does not meet +1- 10% the calibration standard. If the quarterly calibration does not meet the calibration criteria of +1- 15% the meter will be recalibrated and the data in the range that missed the calibration will be considered invalid.

The zero calibration will use 15% of the standard action level of 50 ppb is used as the calibration criteria. The zero calibration must fall between -7.5 ppb and +7.5 ppb for the data to be acceptable. If the meter is reads below -5.0 ppb then a new zero calibration will be completed as soon as feasible. If the meter reads below -7.5 ppb then the data is considered invalid. A logbook of all maintenance work will be maintained for the monitor while a record of all calibration and precision checks will be maintained.

All data will be analyzed for quality and bad data will be removed from the database. The analyzer must meet 75% uptime per quarter.

The MPCA performs annual quality control checks on the ambient TRS monitor system. The MPCA has indicated performance audits require an average error of no greater than +/-1 0%. However, this +1- I0% error is a guideline and should be considered as a warning limit or a line for corrective action. The data produced by a monitor outside this +/-10% limit is still considered valid as long as the percent of error is less than +/-15%.


Internal Monitoring Communications

The monitoring station will be controlled by the mill's Bailey distributed control system (DCS). This will provide real-time data to operators and other personnel in the mill through the mill's computer network. This connection will allow mill personnel to correlate "Episodic odor" events to other runtime process data, which will enable further troubleshooting of TRS emissions. The Recovery Operations Lime Kiln Operator will receive an alarm from the Bailey DCS if an episodic odor event is happening. The Lime Kiln Operator will initiate the Ambient TRS Checklist (attached) procedure to have other mill personnel help investigate and identify the source of the TRS event. A data terminal is installed for the customs building to view wind condition s and TRS levels. The data shall be retained for a period of three years or until the monitoring and reporting aspects of the plan terminate.

Training

Mill personnel associated with the operations of TRS sources and those personnel involved in recording, reporting, or maintaining the ambient monitor will be trained on this plan and the significance of TRS emissions. Training records will be maintained by the department.

Reporting

Reporting requirements of the ambient TRS monitoring plan include immediate (within the next business day) notification of "Episodic odor" events greater than the guideline level, investigation and findings of "Episodic odor" events, and quarterly data reports.

Immediate notification will be made to the Minnesota Pollution Control Agency' s (agency) (Robert Beresford or designee) Duluth, MN office within the next work day of an "Episodic odor" event attributable to the mill. This report shall be via telephone and electronic means, and shall be followed with a written description, if requested by the agency.

All "Episodic odor" events attributable to the mill shall be investigated thoroughly using the Ambient TRS checklist (attached) and reviewed and filed with the Recovery Operations Department. Additionally, an Environmental Incident Report will be electronically filled out. The report shall describe the cause of the incident, steps taken to minimize and/or stop the TRS emissions, corrective action taken and steps necessary to prevent reoccurrence.

"Episodic odor" events that are not within the influence of the mill as stated above, will be investigated in the same manner. These investigations will attempt to identify a single source for the event, however, the accuracy of that determination may not be enough to attribute the event to a single source.

Quarterly data reports will be submitted to the agency within 45 days of the end of a quarter. Boise has worked with the MPCA to provide a data report that fits AIRS data submission formats. Quarterly submittals will also include copies of all "Episodic odor" investigation reports conducted in the quarter.

Monitoring Termination

The monitoring and reporting aspects of this plan shall cease after 730 continuous days of the mill achieving no 1-hour average periods, attributable to the mill, above the TRS guideline. According to the current Air permit, prior to ceasing operation, the MPCA shall issue a public notice to inform the public that the ambient monitoring will cease. Boise shall not cease operation until after the public no t ice per iod .


Disciplined Manufacturing System Ambient TRS Checklist – Lime Kiln Operator

Document No.: 53203109 Revision Date: 09/26/2011 Revision Level: 5 Review Date: 9/26/2011 Issuer: Richard Schaaf Page 1of1 Checklist completed by (KO): _ Date/Time:

Over 50 PPB Ambient TRS -1hr rolling average (PI Tag: 221-AI-OOJC) 1) Kiln Operator: Immediately notify the SOS. 2) Kiln Operator: If the source of TRS is determined immediately and if it is from our facility, notify Shift Supervisor and

Dave Reimer, and proceed to step 14. Note: The Ambient TRS Meter is calibrated on Tuesdays at 1:30PM.

3) Kiln Operator: Review the PI System and Customs Zone of Influence to help determine source of TRS. Note: 320 -350° winds will likely be coming from an off-site source; 240. 320. winds will likely be coming from the I. Falls Mill or SMI. If the wind speed is less than 2.5 mph the Mill is not considered to be the TRS source. If either of these cases are true, skip to step 14.

4) Kiln Operator: Contact the Recovery Operator and Steam Plant Operator. Respective Bailey Screens will be reviewed by Operators for odor related upsets. Field Operators (Recovery, Steam Plant, and Kiln) will immediately go into field to look for abnormalities. The Ambient TRS Response Procedure should be used to help identify Odor Source.

5) Kiln Operator: Contact the Pulp Mill Operator. Bailey Screens will be reviewed and the Pulp Mill Operator will immediately go out field to look at vents for abnormalities.

6) Kiln Operator: Contact the Filter Plant. Bailey Screens will be reviewed and the Filter Plant Operators will immediately go into the field to help identify Odor Source. Look at the UNOX Basin, Clarifiers, SMI, and local H2S alarms on the Lift Stations.

7) Kiln Operator: Receive follow-up calls from Pulp Mill, Recovery, Steam Plant Operators , and the Filter Plant. 8) Kiln Operator: Contact the Pulp/Utilities Production Duty Person, the SOS, and the Recovery Team Leader. 9) Kiln Operator: If the source is not found, contact the Abitibi Supervisor (807-274-5311 ext. 1935). 10) If the source is found and corrected, skip to #12. 11) Source Not Found- Kiln Operator: Update Pulp/Utilities Production Duty Person, the SOS, and the Recovery Team Leader. 12) Operations: Track source again with help from the Pulp/Utilities Production Du 13) Operations: Correct source. 14) Kiln Operator: Enter a detailed Environmental Incident Report. Place checklist on the Recovery Team Leader's Desk.

Over 30 PPB but under 50 PPB Ambient TRS -1hr rolling average (PI Tag: 221-AI-OOJC)

15) Kiln Operator: If source of TRS is determined immediately, correct source (if from our mill), notify SOS, and go to step 25.

16) Kiln Operator: Review the PI System and Customs Zone of lnfluence to help determine source of TRS. Note: 320°-350°winds will likely be coming from an off-site source; 240°-320° winds will likely be coming from the I. Falls Mill or SMI. If the wind speed is less than 2.5 mph, the Mill is not considered the source of the TRS. If either of these cases are true, skip to step 25.

17) Kiln Operator: Contact the Recovery Operator and Steam Plant Operator. Respective Bailey Screens will be reviewed by Operators for odor related upsets. Field Operators (Recovery, Steam Plant, and Kiln) will immediately go into field to look for abnormalities. Ambient TRS Response Procedure used to help identify Odor Source.

18) Kiln Operator: Contact the Pulp Mill Operator. Bailey Screens will be reviewed and the Pulp Mill Field will immediately go out into field to look at vents for abnormalities.

19) Kiln Operator: Contact the Filter Plant. Bailey Screens will be reviewed and the Filter Plant Operators will immediately go out into the field to help identify Odor Source. Look at the UNOX Basin, Clarifiers, SMI, and local H2S alarms on the Lift Stations.

20) Kiln Operator: Receive follow-up calls from Pulp Mill, Recovery, Steam Plant Operators, and the Filter Plant.

21) Kiln Operator: lf the source is not found, call the Abitibi Supervisor (807-274-5311 ext. 1935). 22) Kiln Operator: Notify SOS of Issue. 23) Kiln Operator: Source not found- update the Pulp/Utilities Duty Person. 24) Operations: Correct source.


25) Kiln Operator: Detailed Environmental Incident Report Filed. Place checklist on the Recovery Team Leader's Desk. The Environmental Department will review the EIR on the next business day.

FOLLOW-UP AND FINDINGS FOR AMBIENT TRS Date: What was the source of the TRS? What was the wind direction? What was the duration of the TRS excursion?

Note: An Ambient TRS Alarm requires entering a computer environmental incident report and completing this checklist.


APPENDIX C – Equation to show compliance with 40 CFR Pt. 63, Subp. JJJJ Facility Name: Boise White Paper LLC - Intl Falls Permit Number: 07100002-014 Equation to show compliance with 40 CFR §63.3320(b)(3)

Where: Hs= Monthly average, as-applied, organic HAP to coating solids ratio, kg organic HAP/kg coating solids applied. p = Number of different coating materials applied in a month. Chi= Organic HAP content of coating material, i, as-purchased, expressed as a mass fraction, kg/kg. Mi= Mass of as-purchased coating material, i, applied in a month, kg. q = Number of different materials added to the coating material. Chij= Organic HAP content of material, j, added to as-purchased coating material, i, expressed as a mass fraction, kg/kg. Mij= Mass of material, j, added to as-purchased coating material, i, in a month, kg. Mvret= Mass of volatile matter retained in the coated web after curing or drying, or otherwise not emitted to the atmosphere, kg. The value of this term will be zero in all cases except where you choose to take into account the volatile matter retained in the coated web or otherwise not emitted to the atmosphere for the compliance demonstration procedures in §63.3370. Csi= Coating solids content of coating material, i, expressed as a mass fraction, kg/kg. Csij= Coating solids content of material, j, added to as-purchased coating material, i, expressed as a mass-fraction, kg/kg.


Appendix D - FUGITIVE EMISSIONS CONTROL PLAN Facility Name: Boise White Paper LLC - Intl Falls Permit Number: 07100002-014

FUGITIVE EMISSIONS CONTROL PLAN

· BOISE CASCADE CORPORATION INTERNATIONAL FALLS, MINNESOTA FACILITY Revision for Permit Application 2/14/02 December 28, 1999


Introduction Boise Cascade Corporation (Boise) operates an integrated Kraft pulp and paper mill (mill) in International Falls, Minnesota. The mill manufactures a variety of coated and uncoated fine paper products. The facility consists of a wood-yard, chip processing center, pulp mill, bleach plant, chemical recovery system, power plant, wastewater treatment facility, industrial landfill, paper m ill, finishing and sheeting operations, warehouse, and shipping facilities. Boise received a 40 CFR, part 70 Title V permit (Permit No. 07100002-001) on September 9, 1999, this permit requires the development of a Fugitive Emissions Control plan. The following fugitive sources are covered under this plan: FS 001-002 Log Debarking and Bark Conveying FS 003-007 Bark Piles and handling (Process Center and Landing 8) FS 008 Wood Chipping and Chip Conveying FS 009-010 Wood Chip Pile and Handling FS 011-012 Wood Chip Truck Dump FS 401 Truck Unloading of Bark FS 601 Primary Clarifier FS 603 Secondary Clarifier # I FS 604 Secondary Clarifier #2 FS 701 Paved Vehicle Traffic Emissions FS 702 Unpaved Vehicle Traffic Emissions FS 703 Roundwood Trucks and Logloader Control Strategies Each fugitive emission source listed above is covered by Minn. R. 7007.0150, which requires a facility to 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. Some of the sources also have individual control strategies specific to their operation as described below. FS 001 -002 Log Debarking and Bark Conveying Permittee shall operate in a method that prevents avoidable amounts of fugitive emissions. This shall include maintenance of covers on the conveyors, limitation of drop height from the conveyor to the pile to the minimum amount possible at all times. FS 003-007 Bark Piles and hand ling (Process Center and Landing 8) Permittee shall operate the bark pile in a method that prevents avoidable amounts of fugitive emissions. This shall include the use of a rubber skirt on the discharge of the bark conveyor. Also, when landing 8 is being used Calcium Chloride will be applied to the unpaved areas using the addition rate quantified below in section FS 702


FS 008 Wood Chipping and Chip Conveying Permittee shall operate the wood chip operations in a method that prevents avoidable amounts of fugitive emissions. This shall include maintenance of covers on the conveyors and limitation of drop height from the conveyor to the pile to the minimum amount possible at all times. FS 009-010 Wood Chip Pile and Handling Permittee shall operate in a method that prevents avoidable amounts of fugitive emissions. This shall include maintenance covers on the conveyors limitation of drop height from the conveyor to the pile to the minimum amount possible at all times, and use of water sprays as appropriate during non-freezing weather. FS 011 -012 Wood Chip Truck Dump Permittee shall operate in a method that prevents avoidable amounts of fugitive emissions. This shall include maintenance covers on the conveyors, limitation of drop height from the conveyor to the pile to the minimum amount possible at all times. FS 401 Truck Unloading of Bark Observe mill operations to determine if there is an accumulation of bark that could become airborne or be tracked onto other surfaces. If accumulation of waste occurs, the waste shall be removed from the area. FS 601 Primary Clarifier No additional control strategies. FS 603 Secondary Clarifier # I No additional control strategies. FS 604 Secondary' Clarifier #2 No additional control strategies. FS 701 Paved Vehicle Traffic

The mill shall vacuum sweep roads within the property boundary, except the road to the closed Moonlight Rock landfill, unless the ground is frozen. The equipment shall be operated by the mill and all roads shall be swept twice per week. A Y." rainfall, or greater, may substitute for one sweeping. The mill shall keep the following records: date and extent of each sweeping, with certification from the operator, notes of any areas of high loading or spills, records of equipment breakdowns and repairs, and meteorological records to verify rainfall and frozen ground. The mill shall regularly observe other paved mill roads, including the road to the closed Moonlight Rock landfill, to determine if accumulation of dust or spillage are found and if so, these areas shall be swept in a timely manner.


Permittee shall control all fugitive ash/residue emissions in a manner which will prevent avoidable amounts of particulate matter from becoming airborne. All ash/residue haul trucks containing dry, fine particulate matter leaving the facility must be covered. FS 702 Unpaved Vehicle Traffic Emissions The mill shall regularly observe unpaved mill roads to determine if there is excessive dust or spillage, that could become airborne, and if so, the mill shall take steps to control fugitive emissions, including the use of vegetation on the top of the landfill and the use of light duty vehicles instead of heavy duty vehicles. The amount of emissions has greatly decreased since the land fill was capped and the only vehicle to use the roads on the landfill on a normal basis is for inspection purposes.

Permittee shall control all fugitive ash/residue emissions in a manner, which will prevent avoidable amounts of particulate matter from becoming airborne. All ash/residue haul trucks containing dry, fine particulate matter leaving the facility must be covered. FS 703 Roundwood Trucks and Logloader The mill shall regularly observe travel routes for the roundwood trucks and log loader at the process center to determine if there is excessive dust or spillage, that could become airborne, and if so, the mill shall take steps to control fugitive emissions, including the use of calcium chloride solution as a dust suppressant. Calcium Chloride Addition Rates These travel routes will be sprayed with Calcium Chloride at a rate of at least .17 gallons per square yard during the last two weeks of May, June, July and August. An additional application during the last two weeks of Sept. will be made if excessive dusting is observed. Also, the travel routes will be watered down once between applications to reactivate the calcium Chloride. If necessary second watering will be completed if dusting is excessive. "Note: 0.17 gallons of concentrate per square yard once a month corresponds to a control efficiency of 80%. Reference: October 2001 draft version of AP-42 Section 13.2.2 (Unpaved Roads)." Records This is an ongoing program, all records except watering and Calcium Chloride application dates are kept by the yard crew. Records on water and Calcium Chloride application dates on travel routes will be noted in the Process Center Supervisors Logbook. Revisions This plan will be revised when any there are any changes in operating methods that would require the plan to be revised. A copy of the revision will be forwarded to the Minnesota Pollution Control Agency.


APPENDIX E: Air Toxics Review - January, 1999






















APPENDIX F UNOX Alternative Monitoring

Category: MACT EPA Office: Region 5 Date: 08/14/2002 Title: UNOX Alternative Monitoring Recipient: Eldon Voight Author: George Czerniak

Subparts: Part 63, S, Pulp and Paper Production

References: 63.446 63.453

Abstract:

Q: Can the Boise Cascade paper mill in International Falls, MN use the UNOX system biomass, as calculated using the mixed liquor volatile suspended solids (MLVSS), to meet the continuous monitoring requirements for kraft pulping condensates? The pulp and paper NESHAP does not specify a monitoring parameter for closed biological systems. A: Yes. The UNOX system destruction efficiency depends on the number of biological organisms in the system, the biomass accounts for the majority of organic solids, and MLVSS is a measure of organic solids. Boise Cascade must use the average MLVSS measured during a compliant performance test as the minimum MLVSS demonstrating continuous compliance.

Letter:

August 14, 2002

U.S. Environmental Protection Agency Applicability Determination Index

Control Number: M020009


Eldon Voight, Environmental Engineer Boise Cascade Paper Division 400 Second Street International Falls, Minnesota 56649 Re: Response to the June 10, 2002, request for an expedited review of the Performance Test Proposal for 40 CFR 63.446. Dear Mr. Voight: On June 10, 2002, you wrote a letter to Erik Hardin, of my staff, that contained a clarification of an earlier request, a discussion of the test methodologies you plan to use when testing your UNOX system, and a request to use an alternative monitoring parameter to meet the requirements of 40 CFR Part 63, Subpart S (the Pulp and Paper NESHAP). The primary purpose of this letter is to respond to your request to use an alternative monitoring parameter, but all issues from the letter will be addressed. In the first part of your letter, you retracted a March 12, 2002, request for approval of the use of NCASI Methods 94.02 and 94.03 as these methods are specifically allowed for in the Pulp and Paper NESHAP. You also retracted your previous request to use an alternative procedure for testing emissions from the UNOX system, and you stated that you plan to use test procedures in accordance with 40 CFR Part 63, Appendix C. At this time, U.S. EPA acknowledges this retraction and that no further response to this previous request is required as you now claim that all testing of the UNOX system will be conducted in accordance with the requirements of the Pulp and Paper NESHAP. In the second part of your letter, you state, among other things, that you plan to use NCASI Method 99.01 DI/HAPS when conducting the performance test of the UNOX system. A formal request needs to be made by Boise Cascade to the Emission Monitoring and Analysis Division of U.S. EPA's Office of Air Quality Planning and Standards. In the last part of your letter, you request approval of the use of an alternative monitoring parameter to meet requirements in the Pulp and Paper NESHAP because there is no parameter specified in this rule for closed biological treatment systems. Specifically, you request to use the UNOX system biomass, as calculated using the mixed liquor volatile suspended solids (MLVSS), to meet the continuous monitoring requirements, located at 40 CFR 63.453, which you are required to meet to demonstrate compliance with the emission standards for kraft pulping process condensates, located at 40 CFR 63.446. Because the destruction efficiency of the UNOX system is directly related to the number of biological organisms available to metabolize the organic pollutants in the system and the organic pollutants are the only food source for the organisms (except for other organisms in the system), U.S. EPA believes that the total system biomass is a good indicator of the UNOX system's performance. U.S. EPA also believes that you have provided adequate rationale to demonstrate that the majority of the organic solids in the UNOX system is the biomass. Because MLVSS is a measure of the organic solids, U.S. EPA agrees that MLVSS is a good measure of the UNOX system's performance. Therefore, U.S. EPA approves Boise Cascade's continuous monitoring of total system biomass, as calculated using MLVSS, to meet the continuous monitoring requirements located at 40 CFR 63.453.


Boise Cascade shall use the average MLVSS measured during a performance test of the UNOX system, that demonstrates compliance, as the minimum MLVSS demonstrating continuous compliance during subsequent operation. Boise shall operate the UNOX system in a manner consistent with the minimum MLVSS. Operation of the UNOX system below the minimum MLVSS shall constitute a violation of emissions standards in the Pulp and Paper NESHAP and be reported as a period of excess emissions. If you have any questions regarding this letter, please contact Erik Hardin at (312) 886- 2402. Sincerely yours, George T. Czerniak, Chief Air Enforcement and Compliance Assurance Branch


APPENDIX G Scrubber Pressure Drop Monitoring Parameters

Category: MACT EPA Office: Region 5 Date: 04/27/2004 Title: Scrubber Pressure Drop Monitoring Parameters Recipient: Reimer, David Author: Czerniak, George Comments: See related determinations filed as ADI Control Nos. M050013 and

M050014.

Subparts: Part 63, MM, Pulp Mill Chemical Recovery Combustion Sources

References: 63.8(f)(4)

63.864(e)(10)

Abstract:

Q: Will EPA allow Boise Paper Solutions in International Falls, Minnesota to monitor, under 40 CFR part 63, subpart MM, the scrubber liquid supply pressure in lieu of the pressure drop across the wet scrubber used to control emissions from the lime kiln? A: Yes. EPA will allow this under Maximum Achievable Control Technology (MACT) subpart MM, because for this particular scrubber, liquid supply pressure is a better indicator of scrubber performance and shall be monitored along with liquor flow rate to demonstrate compliance.

Letter:

April 27, 2004 David Reimer, Environmental Manager Boise Paper Soulutions 400 Second Street

U.S. Environmental Protection Agency Applicability Determination Index

Control Number: M050011


International Falls, Minnesota 56649 Re: Response to the January 24, 2004, Request for Alternative Monitoring Method for Lime

Kiln Wet Scrubber Dear Mr.

Reimer:

On January 24, 2004, you requested approval by the United States Environmental Protection Agency (U.S. EPA) of a monitoring procedure other than that required by The National Emission Standards for Hazardous Air Pollutants for Chemical Recovery Combustion Sources at Kraft, Soda, Sulfite, and Stand-Alone Semichemical Pulp Mills (Pulp Mill Combustion NESHAP) at 40 C.F.R. Sec. 63.864(e)(10). Specifically, you requested approval to monitor the scrubber liquid supply pressure in lieu of the pressure drop across the wet scrubber used to control emissions from the lime kiln (the scrubber). You made this request in accordance with the requirements at 40 C.F.R. Sec. 63.8(f)(4)(i). In your request letter, you provide several justifications for monitoring liquid supply pressure in place of pressure drop across the scrubber. First, you indicate that the scrubber operates at a very low pressure drop and that readings may, at times, even be negative values. You also indicate that pressure drop does not affect the performance of the scrubber and provide test data that demonstrates a poor correlation between pressure drop and particulate emissions. The emission data you provided also indicates that scrubber liquid supply pressure is a better indicator of scrubber performance. U.S. EPA has reviewed your request and agrees that adequate rationale exists for the use of an alternative monitoring parameter other than the pressure drop across the scrubber as required by the Pulp Mill Combustion NESHAP. Therefore, for the wet scrubber used to control emissions from the lime kiln at your International Falls, Minnesota facility, scrubbing liquid supply pressure and liquor flow rate shall be monitored to demonstrate compliance with all applicable provisions of the Pulp Mill Combustion NESHAP. If you have any questions regarding this letter, please contact Erik Hardin at (312) 886-2402. Sincerely yours,

George T. Czerniak, Chief Air Enforcement and Compliance Assurance Branch cc: Leonard Lazarus Office of Enforcement and Compliance Assurance United States Environmental Protection Agency Paula Connell Minnesota Pollution Control Agency


APPENDIX H Alternative MACT PM Limits



APPENDIX I MODELING PARAMETERS SO2 2009 NAAQS Modeling (included in permit no. 07100002-011)

SO2 Emission Rates SO2 Emission Rates 1-hour 3-Hour

24-Hour Annual 1-hour 3-Hour

24-Hour Annual

Source ID

Source Description

(TEMPO ID)

Emission Rate

(lb/hr)

Emission Rate

(lb/hr)

Emission Rate

(lb/hr)

Emission Rate (g/s)

Emission Rate (g/s)

Emission Rate

(g/s)

STRU 20

Brownstock Decker (EQUI 44)

1.25

1.25

1.25

0.157

0.157

0.157

STRU 75

CLO2 Generator/Bleach Plant

(COMGs 11 and 12)

0.028

0.028

0.018

0.0036

0.0036

0.0023

STRU 150

Recovery Furnace (EQUI 9)

106.2

106.2

45.7

13.381

13.381

5.753

STRU 110

Smelt Dissolving Tank (EQUI 945)

4.3

4.3

4.3

0.542

0.542

0.542

STRU 111

Lime Kiln (EQUI 13)

13.5

13.5

13.5

1.701

1.701

1.701

STRU 18

Boiler #1 (EQUI 15)

9.40

0.239

0.240

1.184

0.030

0.030

STRU 146

Boiler #2 (EQUI 16)

375.2

384.4

35.70

47.280

48.430

4.498

STRU 147

Boiler #3 (EQUI 17)

0.224

0.224

0.224

0.028

0.028

0.028

SV450 (NO TEMPO ID)

Boiler #8 (retired)

0.123

0.123

0.123

0.016

0.016

0.016

STRU 30

Boiler #9 (EQUI 18)

0.123

0.123

0.123

0.016

0.016

0.016

SO2 sources not included in 2009 modeling or sources with current rates different than above:

TEMPO ID Source Description Emission rate (lb/hr)

EQUI 942 Fire Pump #3 Engine 0.443

COMG 12 Bleach Plant 2.30


NOx emission rates during 1997 PSD Modeling/ current emission rates

TEMPO ID Source Description Emission rates during 1997 modeling (TPY)

Current emission rates (TPY)

EQUI 9 Recovery Furnace 381 482

EQUI 13 Lime Kiln 186 153

EQUI 15 Boiler No. 1 349 349



No TEMPO ID Boiler No. 8 45 Retired


NOx sources not included in 1997 modeling

EQUI 945 Smelt dissolving Tank 8.75

EQUI 941 Lime Kiln Aux. Engine 0.2313

EQUI 942 Fire Pump #3 Engine 1.6740

EQUI 943 Guard Standby Generator 1.4210


Appendix J

40 CFR 60. 63 Subpart A—General Provisions §63.1 Applicability.

(a) General.

(1) Terms used throughout this part are defined in §63.2 or in the Clean Air Act (Act) as amended in 1990, except that individual subparts of this part may include specific definitions in addition to or that supersede definitions in §63.2.

(2) This part contains national emission standards for hazardous air pollutants (NESHAP) established pursuant to section 112 of the Act as amended November 15, 1990. These standards regulate specific categories of stationary sources that emit (or have the potential to emit) one or more hazardous air pollutants listed in this part pursuant to section 112(b) of the Act. This section explains the applicability of such standards to sources affected by them. The standards in this part are independent of NESHAP contained in 40 CFR part 61. The NESHAP in part 61 promulgated by signature of the Administrator before November 15, 1990 (i.e., the date of enactment of the Clean Air Act Amendments of 1990) remain in effect until they are amended, if appropriate, and added to this part.

(3) No emission standard or other requirement established under this part shall be interpreted, construed, or applied to diminish or replace the requirements of a more stringent emission limitation or other applicable requirement established by the Administrator pursuant to other authority of the Act (section 111, part C or D or any other authority of this Act), or a standard issued under State authority. The Administrator may specify in a specific standard under this part that facilities subject to other provisions under the Act need only comply with the provisions of that standard.

(4)(i) Each relevant standard in this part 63 must identify explicitly whether each provision in this subpart A is or is not included in such relevant standard.

(ii) If a relevant part 63 standard incorporates the requirements of 40 CFR part 60, part 61 or other part 63 standards, the relevant part 63 standard must identify explicitly the applicability of each corresponding part 60, part 61, or other part 63 subpart A (General) provision.

(iii) The General Provisions in this subpart A do not apply to regulations developed pursuant to section 112(r) of the amended Act, unless otherwise specified in those regulations.

(5) [Reserved]

(6) To obtain the most current list of categories of sources to be regulated under section 112 of the Act, or to obtain the most recent regulation promulgation schedule established pursuant to section 112(e) of the Act, contact the Office of the Director, Emission Standards Division, Office of Air Quality Planning and Standards, U.S. EPA (MD-13), Research Triangle Park, North Carolina 27711.

(7)-(9) [Reserved]

(10) For the purposes of this part, time periods specified in days shall be measured in calendar days, even if the word “calendar” is absent, unless otherwise specified in an applicable requirement.

(11) For the purposes of this part, if an explicit postmark deadline is not specified in an applicable requirement for the submittal of a notification, application, test plan, report, or other written communication to the Administrator, the owner or operator shall postmark the submittal on or before the number of days specified in the applicable requirement. For example, if a notification must be submitted 15 days before a particular event is scheduled to take place, the notification shall be postmarked on or before 15 days preceding the event; likewise, if a notification must be submitted 15 days after a particular event takes place, the notification shall be postmarked on or before 15 days following the end of the event. The use of reliable non-Government mail carriers that provide indications of verifiable delivery of information required to


be submitted to the Administrator, similar to the postmark provided by the U.S. Postal Service, or alternative means of delivery agreed to by the permitting authority, is acceptable.

(12) Notwithstanding time periods or postmark deadlines specified in this part for the submittal of information to the Administrator by an owner or operator, or the review of such information by the Administrator, such time periods or deadlines may be changed by mutual agreement between the owner or operator and the Administrator. Procedures governing the implementation of this provision are specified in §63.9(i).

(b) Initial applicability determination for this part. (1) The provisions of this part apply to the owner or operator of any stationary source that—

(i) Emits or has the potential to emit any hazardous air pollutant listed in or pursuant to section 112(b) of the Act; and

(ii) Is subject to any standard, limitation, prohibition, or other federally enforceable requirement established pursuant to this part.

(2) [Reserved]

(3) An owner or operator of a stationary source who is in the relevant source category and who determines that the source is not subject to a relevant standard or other requirement established under this part must keep a record as specified in §63.10(b)(3).

(c) Applicability of this part after a relevant standard has been set under this part. (1) If a relevant standard has been established under this part, the owner or operator of an affected source must comply with the provisions of that standard and of this subpart as provided in paragraph (a)(4) of this section.

(2) Except as provided in §63.10(b)(3), if a relevant standard has been established under this part, the owner or operator of an affected source may be required to obtain a title V permit from a permitting authority in the State in which the source is located. Emission standards promulgated in this part for area sources pursuant to section 112(c)(3) of the Act will specify whether—

(i) States will have the option to exclude area sources affected by that standard from the requirement to obtain a title V permit (i.e., the standard will exempt the category of area sources altogether from the permitting requirement);

(ii) States will have the option to defer permitting of area sources in that category until the Administrator takes rulemaking action to determine applicability of the permitting requirements; or

(iii) If a standard fails to specify what the permitting requirements will be for area sources affected by such a standard, then area sources that are subject to the standard will be subject to the requirement to obtain a title V permit without any deferral.

(3)-(4) [Reserved]

(5) If an area source that otherwise would be subject to an emission standard or other requirement established under this part if it were a major source subsequently increases its emissions of hazardous air pollutants (or its potential to emit hazardous air pollutants) such that the source is a major source that is subject to the emission standard or other requirement, such source also shall be subject to the notification requirements of this subpart.

(d) [Reserved]

(e) If the Administrator promulgates an emission standard under section 112(d) or (h) of the Act that is applicable to a source subject to an emission limitation by permit established under section 112(j) of the Act, and the requirements under the section 112(j) emission limitation are substantially as effective as the promulgated emission standard, the owner or operator may request the permitting authority to revise the source's title V permit to reflect that the emission limitation in


the permit satisfies the requirements of the promulgated emission standard. The process by which the permitting authority determines whether the section 112(j) emission limitation is substantially as effective as the promulgated emission standard must include, consistent with part 70 or 71 of this chapter, the opportunity for full public, EPA, and affected State review (including the opportunity for EPA's objection) prior to the permit revision being finalized. A negative determination by the permitting authority constitutes final action for purposes of review and appeal under the applicable title V operating permit program.

§63.2 Definitions.

The terms used in this part are defined in the Act or in this section as follows:

Act means the Clean Air Act (42 U.S.C. 7401 et seq., as amended by Pub. L. 101-549, 104 Stat. 2399).

Actual emissions is defined in subpart D of this part for the purpose of granting a compliance extension for an early reduction of hazardous air pollutants.

Administrator means the Administrator of the United States Environmental Protection Agency or his or her authorized representative (e.g., a State that has been delegated the authority to implement the provisions of this part).

Affected source, for the purposes of this part, means the collection of equipment, activities, or both within a single contiguous area and under common control that is included in a section 112(c) source category or subcategory for which a section 112(d) standard or other relevant standard is established pursuant to section 112 of the Act. Each relevant standard will define the “affected source,” as defined in this paragraph unless a different definition is warranted based on a published justification as to why this definition would result in significant administrative, practical, or implementation problems and why the different definition would resolve those problems. The term “affected source,” as used in this part, is separate and distinct from any other use of that term in EPA regulations such as those implementing title IV of the Act. Affected source may be defined differently for part 63 than affected facility and stationary source in parts 60 and 61, respectively. This definition of “affected source,” and the procedures for adopting an alternative definition of “affected source,” shall apply to each section 112(d) standard for which the initial proposed rule is signed by the Administrator after June 30, 2002.

Alternative emission limitation means conditions established pursuant to sections 112(i)(5) or 112(i)(6) of the Act by the Administrator or by a State with an approved permit program.

Alternative emission standard means an alternative means of emission limitation that, after notice and opportunity for public comment, has been demonstrated by an owner or operator to the Administrator's satisfaction to achieve a reduction in emissions of any air pollutant at least equivalent to the reduction in emissions of such pollutant achieved under a relevant design, equipment, work practice, or operational emission standard, or combination thereof, established under this part pursuant to section 112(h) of the Act.

Alternative test method means any method of sampling and analyzing for an air pollutant that is not a test method in this chapter and that has been demonstrated to the Administrator's satisfaction, using Method 301 in appendix A of this part, to produce results adequate for the Administrator's determination that it may be used in place of a test method specified in this part.

Approved permit program means a State permit program approved by the Administrator as meeting the requirements of part 70 of this chapter or a Federal permit program established in this chapter pursuant to title V of the Act (42 U.S.C. 7661).

Area source means any stationary source of hazardous air pollutants that is not a major source as defined in this part.

Commenced means, with respect to construction or reconstruction of an affected source, that an owner or operator has undertaken a continuous program of construction or reconstruction or that an owner or operator has entered into a contractual obligation to undertake and complete, within a reasonable time, a continuous program of construction or reconstruction.


Compliance date means the date by which an affected source is required to be in compliance with a relevant standard, limitation, prohibition, or any federally enforceable requirement established by the Administrator (or a State with an approved permit program) pursuant to section 112 of the Act.

Compliance schedule means:

(1) In the case of an affected source that is in compliance with all applicable requirements established under this part, a statement that the source will continue to comply with such requirements; or

(2) In the case of an affected source that is required to comply with applicable requirements by a future date, a statement that the source will meet such requirements on a timely basis and, if required by an applicable requirement, a detailed schedule of the dates by which each step toward compliance will be reached; or

(3) In the case of an affected source not in compliance with all applicable requirements established under this part, a schedule of remedial measures, including an enforceable sequence of actions or operations with milestones and a schedule for the submission of certified progress reports, where applicable, leading to compliance with a relevant standard, limitation, prohibition, or any federally enforceable requirement established pursuant to section 112 of the Act for which the affected source is not in compliance. This compliance schedule shall resemble and be at least as stringent as that contained in any judicial consent decree or administrative order to which the source is subject. Any such schedule of compliance shall be supplemental to, and shall not sanction noncompliance with, the applicable requirements on which it is based.

Construction means the on-site fabrication, erection, or installation of an affected source. Construction does not include the removal of all equipment comprising an affected source from an existing location and reinstallation of such equipment at a new location. The owner or operator of an existing affected source that is relocated may elect not to reinstall minor ancillary equipment including, but not limited to, piping, ductwork, and valves. However, removal and reinstallation of an affected source will be construed as reconstruction if it satisfies the criteria for reconstruction as defined in this section. The costs of replacing minor ancillary equipment must be considered in determining whether the existing affected source is reconstructed.

Continuous emission monitoring system (CEMS) means the total equipment that may be required to meet the data acquisition and availability requirements of this part, used to sample, condition (if applicable), analyze, and provide a record of emissions.

Continuous monitoring system (CMS) is a comprehensive term that may include, but is not limited to, continuous emission monitoring systems, continuous opacity monitoring systems, continuous parameter monitoring systems, or other manual or automatic monitoring that is used for demonstrating compliance with an applicable regulation on a continuous basis as defined by the regulation.

Continuous opacity monitoring system (COMS) means a continuous monitoring system that measures the opacity of emissions.

Continuous parameter monitoring system means the total equipment that may be required to meet the data acquisition and availability requirements of this part, used to sample, condition (if applicable), analyze, and provide a record of process or control system parameters.

Effective date means:

(1) With regard to an emission standard established under this part, the date of promulgation in the Federal Register of such standard; or

(2) With regard to an alternative emission limitation or equivalent emission limitation determined by the Administrator (or a State with an approved permit program), the date that the alternative emission limitation or equivalent emission limitation becomes effective according to the provisions of this part.


Emission standard means a national standard, limitation, prohibition, or other regulation promulgated in a subpart of this part pursuant to sections 112(d), 112(h), or 112(f) of the Act.

Emissions averaging is a way to comply with the emission limitations specified in a relevant standard, whereby an affected source, if allowed under a subpart of this part, may create emission credits by reducing emissions from specific points to a level below that required by the relevant standard, and those credits are used to offset emissions from points that are not controlled to the level required by the relevant standard.

EPA means the United States Environmental Protection Agency.

Equivalent emission limitation means any maximum achievable control technology emission limitation or requirements which are applicable to a major source of hazardous air pollutants and are adopted by the Administrator (or a State with an approved permit program) on a case-by-case basis, pursuant to section 112(g) or (j) of the Act.

Excess emissions and continuous monitoring system performance report is a report that must be submitted periodically by an affected source in order to provide data on its compliance with relevant emission limits, operating parameters, and the performance of its continuous parameter monitoring systems.

Existing source means any affected source that is not a new source.

Federally enforceable means all limitations and conditions that are enforceable by the Administrator and citizens under the Act or that are enforceable under other statutes administered by the Administrator. Examples of federally enforceable limitations and conditions include, but are not limited to:

(1) Emission standards, alternative emission standards, alternative emission limitations, and equivalent emission limitations established pursuant to section 112 of the Act as amended in 1990;

(2) New source performance standards established pursuant to section 111 of the Act, and emission standards established pursuant to section 112 of the Act before it was amended in 1990;

(3) All terms and conditions in a title V permit, including any provisions that limit a source's potential to emit, unless expressly designated as not federally enforceable;

(4) Limitations and conditions that are part of an approved State Implementation Plan (SIP) or a Federal Implementation Plan (FIP);

(5) Limitations and conditions that are part of a Federal construction permit issued under 40 CFR 52.21 or any construction permit issued under regulations approved by the EPA in accordance with 40 CFR part 51;

(6) Limitations and conditions that are part of an operating permit where the permit and the permitting program pursuant to which it was issued meet all of the following criteria:

(i) The operating permit program has been submitted to and approved by EPA into a State implementation plan (SIP) under section 110 of the CAA;

(ii) The SIP imposes a legal obligation that operating permit holders adhere to the terms and limitations of such permits and provides that permits which do not conform to the operating permit program requirements and the requirements of EPA's underlying regulations may be deemed not “federally enforceable” by EPA;

(iii) The operating permit program requires that all emission limitations, controls, and other requirements imposed by such permits will be at least as stringent as any other applicable limitations and requirements contained in the SIP or enforceable under the SIP, and that the program may not issue permits that waive, or make less stringent, any limitations or requirements contained in or issued pursuant to the SIP, or that are otherwise “federally enforceable”;

(iv) The limitations, controls, and requirements in the permit in question are permanent, quantifiable, and otherwise enforceable as a practical matter; and


(v) The permit in question was issued only after adequate and timely notice and opportunity for comment for EPA and the public.

(7) Limitations and conditions in a State rule or program that has been approved by the EPA under subpart E of this part for the purposes of implementing and enforcing section 112; and

(8) Individual consent agreements that the EPA has legal authority to create.

Fixed capital cost means the capital needed to provide all the depreciable components of an existing source.

Force majeure means, for purposes of §63.7, an event that will be or has been caused by circumstances beyond the control of the affected facility, its contractors, or any entity controlled by the affected facility that prevents the owner or operator from complying with the regulatory requirement to conduct performance tests within the specified timeframe despite the affected facility's best efforts to fulfill the obligation. Examples of such events are acts of nature, acts of war or terrorism, or equipment failure or safety hazard beyond the control of the affected facility.

Fugitive emissions means those emissions from a stationary source that could not reasonably pass through a stack, chimney, vent, or other functionally equivalent opening. Under section 112 of the Act, all fugitive emissions are to be considered in determining whether a stationary source is a major source.

Hazardous air pollutant means any air pollutant listed in or pursuant to section 112(b) of the Act.

Issuance of a part 70 permit will occur, if the State is the permitting authority, in accordance with the requirements of part 70 of this chapter and the applicable, approved State permit program. When the EPA is the permitting authority, issuance of a title V permit occurs immediately after the EPA takes final action on the final permit.

Major source means any stationary source or group of stationary sources located within a contiguous area and under common control that emits or has the potential to emit considering controls, in the aggregate, 10 tons per year or more of any hazardous air pollutant or 25 tons per year or more of any combination of hazardous air pollutants, unless the Administrator establishes a lesser quantity, or in the case of radionuclides, different criteria from those specified in this sentence.

Malfunction means any sudden, infrequent, and not reasonably preventable failure of air pollution control and monitoring equipment, process equipment, or a process to operate in a normal or usual manner which causes, or has the potential to cause, the emission limitations in an applicable standard to be exceeded. Failures that are caused in part by poor maintenance or careless operation are not malfunctions.

Monitoring means the collection and use of measurement data or other information to control the operation of a process or pollution control device or to verify a work practice standard relative to assuring compliance with applicable requirements. Monitoring is composed of four elements:

(1) Indicator(s) of performance—the parameter or parameters you measure or observe for demonstrating proper operation of the pollution control measures or compliance with the applicable emissions limitation or standard. Indicators of performance may include direct or predicted emissions measurements (including opacity), operational parametric values that correspond to process or control device (and capture system) efficiencies or emissions rates, and recorded findings of inspection of work practice activities, materials tracking, or design characteristics. Indicators may be expressed as a single maximum or minimum value, a function of process variables (for example, within a range of pressure drops), a particular operational or work practice status (for example, a damper position, completion of a waste recovery task, materials tracking), or an interdependency between two or among more than two variables.

(2) Measurement techniques—the means by which you gather and record information of or about the indicators of performance. The components of the measurement technique include the detector type, location and installation specifications, inspection procedures, and quality assurance and quality control measures. Examples of measurement techniques include continuous emission monitoring systems, continuous opacity monitoring systems, continuous parametric monitoring systems, and manual inspections that include making records of process conditions or work practices.


(3) Monitoring frequency—the number of times you obtain and record monitoring data over a specified time interval. Examples of monitoring frequencies include at least four points equally spaced for each hour for continuous emissions or parametric monitoring systems, at least every 10 seconds for continuous opacity monitoring systems, and at least once per operating day (or week, month, etc.) for work practice or design inspections.

(4) Averaging time—the period over which you average and use data to verify proper operation of the pollution control approach or compliance with the emissions limitation or standard. Examples of averaging time include a 3-hour average in units of the emissions limitation, a 30-day rolling average emissions value, a daily average of a control device operational parametric range, and an instantaneous alarm.

New affected source means the collection of equipment, activities, or both within a single contiguous area and under common control that is included in a section 112(c) source category or subcategory that is subject to a section 112(d) or other relevant standard for new sources. This definition of “new affected source,” and the criteria to be utilized in implementing it, shall apply to each section 112(d) standard for which the initial proposed rule is signed by the Administrator after June 30, 2002. Each relevant standard will define the term “new affected source,” which will be the same as the “affected source” unless a different collection is warranted based on consideration of factors including:

(1) Emission reduction impacts of controlling individual sources versus groups of sources;

(2) Cost effectiveness of controlling individual equipment;

(3) Flexibility to accommodate common control strategies;

(4) Cost/benefits of emissions averaging;

(5) Incentives for pollution prevention;

(6) Feasibility and cost of controlling processes that share common equipment (e.g., product recovery devices);

(7) Feasibility and cost of monitoring; and

(8) Other relevant factors.

New source means any affected source the construction or reconstruction of which is commenced after the Administrator first proposes a relevant emission standard under this part establishing an emission standard applicable to such source.

One-hour period, unless otherwise defined in an applicable subpart, means any 60-minute period commencing on the hour.

Opacity means the degree to which emissions reduce the transmission of light and obscure the view of an object in the background. For continuous opacity monitoring systems, opacity means the fraction of incident light that is attenuated by an optical medium.

Owner or operator means any person who owns, leases, operates, controls, or supervises a stationary source.

Performance audit means a procedure to analyze blind samples, the content of which is known by the Administrator, simultaneously with the analysis of performance test samples in order to provide a measure of test data quality.

Performance evaluation means the conduct of relative accuracy testing, calibration error testing, and other measurements used in validating the continuous monitoring system data.

Performance test means the collection of data resulting from the execution of a test method (usually three emission test runs) used to demonstrate compliance with a relevant emission standard as specified in the performance test section of the relevant standard.

Permit modification means a change to a title V permit as defined in regulations codified in this chapter to implement title V of the Act (42 U.S.C. 7661).


Permit program means a comprehensive State operating permit system established pursuant to title V of the Act (42 U.S.C. 7661) and regulations codified in part 70 of this chapter and applicable State regulations, or a comprehensive Federal operating permit system established pursuant to title V of the Act and regulations codified in this chapter.

Permit revision means any permit modification or administrative permit amendment to a title V permit as defined in regulations codified in this chapter to implement title V of the Act (42 U.S.C. 7661).

Permitting authority means:

(1) The State air pollution control agency, local agency, other State agency, or other agency authorized by the Administrator to carry out a permit program under part 70 of this chapter; or

(2) The Administrator, in the case of EPA-implemented permit programs under title V of the Act (42 U.S.C. 7661).

Pollution Prevention means source reduction as defined under the Pollution Prevention Act (42 U.S.C. 13101-13109). The definition is as follows:

(1) Source reduction is any practice that:

(i) Reduces the amount of any hazardous substance, pollutant, or contaminant entering any waste stream or otherwise released into the environment (including fugitive emissions) prior to recycling, treatment, or disposal; and

(ii) Reduces the hazards to public health and the environment associated with the release of such substances, pollutants, or contaminants.

(2) The term source reduction includes equipment or technology modifications, process or procedure modifications, reformulation or redesign of products, substitution of raw materials, and improvements in housekeeping, maintenance, training, or inventory control.

(3) The term source reduction does not include any practice that alters the physical, chemical, or biological characteristics or the volume of a hazardous substance, pollutant, or contaminant through a process or activity which itself is not integral to and necessary for the production of a product or the providing of a service.

Potential to emit means the maximum capacity of a stationary source to emit a pollutant under its physical and operational design. Any physical or operational limitation on the capacity of the stationary source to emit a pollutant, including air pollution control equipment and restrictions on hours of operation or on the type or amount of material combusted, stored, or processed, shall be treated as part of its design if the limitation or the effect it would have on emissions is federally enforceable.

Reconstruction, unless otherwise defined in a relevant standard, means the replacement of components of an affected or a previously nonaffected source 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 new source; and

(2) It is technologically and economically feasible for the reconstructed source to meet the relevant standard(s) established by the Administrator (or a State) pursuant to section 112 of the Act. Upon reconstruction, an affected source, or a stationary source that becomes an affected source, is subject to relevant standards for new sources, including compliance dates, irrespective of any change in emissions of hazardous air pollutants from that source.

Regulation promulgation schedule means the schedule for the promulgation of emission standards under this part, established by the Administrator pursuant to section 112(e) of the Act and published in the Federal Register.

Relevant standard means:

(1) An emission standard;


(2) An alternative emission standard;

(3) An alternative emission limitation; or

(4) An equivalent emission limitation established pursuant to section 112 of the Act that applies to the collection of equipment, activities, or both regulated by such standard or limitation. A relevant standard may include or consist of a design, equipment, work practice, or operational requirement, or other measure, process, method, system, or technique (including prohibition of emissions) that the Administrator (or a State) establishes for new or existing sources to which such standard or limitation applies. Every relevant standard established pursuant to section 112 of the Act includes subpart A of this part, as provided by §63.1(a)(4), and all applicable appendices of this part or of other parts of this chapter that are referenced in that standard.

Responsible official means one of the following:

(1) For a corporation: A president, secretary, treasurer, or vice president of the corporation in charge of a principal business function, or any other person who performs similar policy or decision-making functions for the corporation, or a duly authorized representative of such person if the representative is responsible for the overall operation of one or more manufacturing, production, or operating facilities and either:

(i) The facilities employ more than 250 persons or have gross annual sales or expenditures exceeding $25 million (in second quarter 1980 dollars); or

(ii) The delegation of authority to such representative is approved in advance by the Administrator.

(2) For a partnership or sole proprietorship: a general partner or the proprietor, respectively.

(3) For a municipality, State, Federal, or other public agency: either a principal executive officer or ranking elected official. For the purposes of this part, a principal executive officer of a Federal agency includes the chief executive officer having responsibility for the overall operations of a principal geographic unit of the agency (e.g., a Regional Administrator of the EPA).

(4) For affected sources (as defined in this part) applying for or subject to a title V permit: “responsible official” shall have the same meaning as defined in part 70 or Federal title V regulations in this chapter (42 U.S.C. 7661), whichever is applicable.

Run means one of a series of emission or other measurements needed to determine emissions for a representative operating period or cycle as specified in this part.

Shutdown means the cessation of operation of an affected source or portion of an affected source for any purpose.

Six-minute period means, with respect to opacity determinations, any one of the 10 equal parts of a 1-hour period.

Source at a Performance Track member facility means a major or area source located at a facility which has been accepted by EPA for membership in the Performance Track Program (as described at www.epa.gov/PerformanceTrack) and is still a member of the Program. The Performance Track Program is a voluntary program that encourages continuous environmental improvement through the use of environmental management systems, local community outreach, and measurable results.

Standard conditions means a temperature of 293 K (68 °F) and a pressure of 101.3 kilopascals (29.92 in. Hg).

Startup means the setting in operation of an affected source or portion of an affected source for any purpose.

State means all non-Federal authorities, including local agencies, interstate associations, and State-wide programs, that have delegated authority to implement: (1) The provisions of this part and/or (2) the permit program established under part 70 of this chapter. The term State shall have its conventional meaning where clear from the context.

Stationary source means any building, structure, facility, or installation which emits or may emit any air pollutant.


Test method means the validated procedure for sampling, preparing, and analyzing for an air pollutant specified in a relevant standard as the performance test procedure. The test method may include methods described in an appendix of this chapter, test methods incorporated by reference in this part, or methods validated for an application through procedures in Method 301 of appendix A of this part.

Title V permit means any permit issued, renewed, or revised pursuant to Federal or State regulations established to implement title V of the Act (42 U.S.C. 7661). A title V permit issued by a State permitting authority is called a part 70 permit in this part.

Visible emission means the observation of an emission of opacity or optical density above the threshold of vision.

Working day means any day on which Federal Government offices (or State government offices for a State that has obtained delegation under section 112(l)) are open for normal business. Saturdays, Sundays, and official Federal (or where delegated, State) holidays are not working days.

§63.3 Units and abbreviations.

Used in this part are abbreviations and symbols of units of measure. These are defined as follows:

(a) System International (SI) units of measure:

A = ampere

g = gram

Hz = hertz

J = joule

°K = degree Kelvin

kg = kilogram

l = liter

m = meter

m3 = cubic meter

mg = milligram = 10−3 gram

ml = milliliter = 10−3 liter

mm = millimeter = 10−3 meter

Mg = megagram = 106 gram = metric ton

MJ = megajoule

mol = mole

N = newton

ng = nanogram = 10−9 gram

nm = nanometer = 10−9 meter

Pa = pascal

s = second

V = volt


W = watt

Ω = ohm

µg = microgram = 10−6 gram

µl = microliter = 10−6 liter

(b) Other units of measure:

Btu = British thermal unit

°C = degree Celsius (centigrade)

cal = calorie

cfm = cubic feet per minute

cc = cubic centimeter

cu ft = cubic feet

d = day

dcf = dry cubic feet

dcm = dry cubic meter

dscf = dry cubic feet at standard conditions

dscm = dry cubic meter at standard conditions

eq = equivalent

°F degree Fahrenheit

ft = feet

ft2 = square feet

ft3 = cubic feet

gal = gallon

gr = grain

g-eq = gram equivalent

g-mole = gram mole

hr = hour

in. = inch

in. H2 O = inches of water

K = 1,000

kcal = kilocalorie

lb = pound

lpm = liter per minute

meq = milliequivalent


min = minute

MW = molecular weight

oz = ounces

ppb = parts per billion

ppbw = parts per billion by weight

ppbv = parts per billion by volume

ppm = parts per million

ppmw = parts per million by weight

ppmv = parts per million by volume

psia = pounds per square inch absolute

psig = pounds per square inch gage

°R = degree Rankine

scf = cubic feet at standard conditions

scfh = cubic feet at standard conditions per hour

scm = cubic meter at standard conditions

scmm = cubic meter at standard conditions per minute

sec = second

sq ft = square feet

std = at standard conditions

v/v = volume per volume

yd2 = square yards

yr = year

(c) Miscellaneous:

act = actual

avg = average

I.D. = inside diameter

M = molar

N = normal

O.D. = outside diameter

% = percent

§63.4 Prohibited activities and circumvention.

(a) Prohibited activities.


(1) No owner or operator subject to the provisions of this part must operate any affected source in violation of the requirements of this part. Affected sources subject to and in compliance with either an extension of compliance or an exemption from compliance are not in violation of the requirements of this part. An extension of compliance can be granted by the Administrator under this part; by a State with an approved permit program; or by the President under section 112(i)(4) of the Act.

(2) No owner or operator subject to the provisions of this part shall fail to keep records, notify, report, or revise reports as required under this part.

(3)-(5) [Reserved]

(b) Circumvention. No owner or operator subject to the provisions of this part shall build, erect, install, or use any article, machine, equipment, or process to conceal an emission that would otherwise constitute noncompliance with a relevant standard. Such concealment includes, but is not limited to—

(1) The use of diluents to achieve compliance with a relevant standard based on the concentration of a pollutant in the effluent discharged to the atmosphere;

(2) The use of gaseous diluents to achieve compliance with a relevant standard for visible emissions; and

(c) Fragmentation. Fragmentation after November 15, 1990 which divides ownership of an operation, within the same facility among various owners where there is no real change in control, will not affect applicability. The owner and operator must not use fragmentation or phasing of reconstruction activities (i.e., intentionally dividing reconstruction into multiple parts for purposes of avoiding new source requirements) to avoid becoming subject to new source requirements.

§63.5 Preconstruction review and notification requirements.

(a) Applicability.

(1) This section implements the preconstruction review requirements of section 112(i)(1). After the effective date of a relevant standard, promulgated pursuant to section 112(d), (f), or (h) of the Act, under this part, the preconstruction review requirements in this section apply to the owner or operator of new affected sources and reconstructed affected sources that are major-emitting as specified in this section. New and reconstructed affected sources that commence construction or reconstruction before the effective date of a relevant standard are not subject to the preconstruction review requirements specified in paragraphs (b)(3), (d), and (e) of this section.

(2) This section includes notification requirements for new affected sources and reconstructed affected sources that are not major-emitting affected sources and that are or become subject to a relevant promulgated emission standard after the effective date of a relevant standard promulgated under this part.

(b) Requirements for existing, newly constructed, and reconstructed sources. (1) A new affected source for which construction commences after proposal of a relevant standard is subject to relevant standards for new affected sources, including compliance dates. An affected source for which reconstruction commences after proposal of a relevant standard is subject to relevant standards for new sources, including compliance dates, irrespective of any change in emissions of hazardous air pollutants from that source.

(2) [Reserved]

(3) After the effective date of any relevant standard promulgated by the Administrator under this part, no person may, without obtaining written approval in advance from the Administrator in accordance with the procedures specified in paragraphs (d) and (e) of this section, do any of the following:

(i) Construct a new affected source that is major-emitting and subject to such standard;

(ii) Reconstruct an affected source that is major-emitting and subject to such standard; or


(iii) Reconstruct a major source such that the source becomes an affected source that is major-emitting and subject to the standard.

(4) After the effective date of any relevant standard promulgated by the Administrator under this part, an owner or operator who constructs a new affected source that is not major-emitting or reconstructs an affected source that is not major-emitting that is subject to such standard, or reconstructs a source such that the source becomes an affected source subject to the standard, must notify the Administrator of the intended construction or reconstruction. The notification must be submitted in accordance with the procedures in §63.9(b).

(5) [Reserved]

(6) After the effective date of any relevant standard promulgated by the Administrator under this part, equipment added (or a process change) to an affected source that is within the scope of the definition of affected source under the relevant standard must be considered part of the affected source and subject to all provisions of the relevant standard established for that affected source.

(c) [Reserved]

(d) Application for approval of construction or reconstruction. The provisions of this paragraph implement section 112(i)(1) of the Act.

(1) General application requirements. (i) An owner or operator who is subject to the requirements of paragraph (b)(3) of this section must submit to the Administrator an application for approval of the construction or reconstruction. The application must be submitted as soon as practicable before actual construction or reconstruction begins. The application for approval of construction or reconstruction may be used to fulfill the initial notification requirements of §63.9(b)(5). The owner or operator may submit the application for approval well in advance of the date actual construction or reconstruction begins in order to ensure a timely review by the Administrator and that the planned date to begin will not be delayed.

(ii) A separate application shall be submitted for each construction or reconstruction. Each application for approval of construction or reconstruction shall include at a minimum:

(A) The applicant's name and address;

(B) A notification of intention to construct a new major affected source or make any physical or operational change to a major affected source that may meet or has been determined to meet the criteria for a reconstruction, as defined in §63.2 or in the relevant standard;

(C) The address (i.e., physical location) or proposed address of the source;

(D) An identification of the relevant standard that is the basis of the application;

(E) The expected date of the beginning of actual construction or reconstruction;

(F) The expected completion date of the construction or reconstruction;

(G) [Reserved]

(H) The type and quantity of hazardous air pollutants emitted by the source, reported in units and averaging times and in accordance with the test methods specified in the relevant standard, or if actual emissions data are not yet available, an estimate of the type and quantity of hazardous air pollutants expected to be emitted by the source reported in units and averaging times specified in the relevant standard. The owner or operator may submit percent reduction information if a relevant standard is established in terms of percent reduction. However, operating parameters, such as flow rate, shall be included in the submission to the extent that they demonstrate performance and compliance; and

(I) [Reserved]


(J) Other information as specified in paragraphs (d)(2) and (d)(3) of this section.

(iii) An owner or operator who submits estimates or preliminary information in place of the actual emissions data and analysis required in paragraphs (d)(1)(ii)(H) and (d)(2) of this section shall submit the actual, measured emissions data and other correct information as soon as available but no later than with the notification of compliance status required in §63.9(h) (see §63.9(h)(5)).

(2) Application for approval of construction. Each application for approval of construction must include, in addition to the information required in paragraph (d)(1)(ii) of this section, technical information describing the proposed nature, size, design, operating design capacity, and method of operation of the source, including an identification of each type of emission point for each type of hazardous air pollutant that is emitted (or could reasonably be anticipated to be emitted) and a description of the planned air pollution control system (equipment or method) for each emission point. The description of the equipment to be used for the control of emissions must include each control device for each hazardous air pollutant and the estimated control efficiency (percent) for each control device. The description of the method to be used for the control of emissions must include an estimated control efficiency (percent) for that method. Such technical information must include calculations of emission estimates in sufficient detail to permit assessment of the validity of the calculations.

(3) Application for approval of reconstruction. Each application for approval of reconstruction shall include, in addition to the information required in paragraph (d)(1)(ii) of this section—

(i) A brief description of the affected source and the components that are to be replaced;

(ii) A description of present and proposed emission control systems (i.e., equipment or methods). The description of the equipment to be used for the control of emissions shall include each control device for each hazardous air pollutant and the estimated control efficiency (percent) for each control device. The description of the method to be used for the control of emissions shall include an estimated control efficiency (percent) for that method. Such technical information shall include calculations of emission estimates in sufficient detail to permit assessment of the validity of the calculations;

(iii) An estimate of the fixed capital cost of the replacements and of constructing a comparable entirely new source;

(iv) The estimated life of the affected source after the replacements; and

(v) A discussion of any economic or technical limitations the source may have in complying with relevant standards or other requirements after the proposed replacements. The discussion shall be sufficiently detailed to demonstrate to the Administrator's satisfaction that the technical or economic limitations affect the source's ability to comply with the relevant standard and how they do so.

(vi) If in the application for approval of reconstruction the owner or operator designates the affected source as a reconstructed source and declares that there are no economic or technical limitations to prevent the source from complying with all relevant standards or other requirements, the owner or operator need not submit the information required in paragraphs (d)(3)(iii) through (d)(3)(v) of this section.

(4) Additional information. The Administrator may request additional relevant information after the submittal of an application for approval of construction or reconstruction.

(e) Approval of construction or reconstruction. (1)(i) If the Administrator determines that, if properly constructed, or reconstructed, and operated, a new or existing source for which an application under paragraph (d) of this section was submitted will not cause emissions in violation of the relevant standard(s) and any other federally enforceable requirements, the Administrator will approve the construction or reconstruction.

(ii) In addition, in the case of reconstruction, the Administrator's determination under this paragraph will be based on:


(A) The fixed capital cost of the replacements in comparison to the fixed capital cost that would be required to construct a comparable entirely new source;

(B) The estimated life of the source after the replacements compared to the life of a comparable entirely new source;

(C) The extent to which the components being replaced cause or contribute to the emissions from the source; and

(D) Any economic or technical limitations on compliance with relevant standards that are inherent in the proposed replacements.

(2)(i) The Administrator will notify the owner or operator in writing of approval or intention to deny approval of construction or reconstruction within 60 calendar days after receipt of sufficient information to evaluate an application submitted under paragraph (d) of this section. The 60-day approval or denial period will begin after the owner or operator has been notified in writing that his/her application is complete. The Administrator will notify the owner or operator in writing of the status of his/her application, that is, whether the application contains sufficient information to make a determination, within 30 calendar days after receipt of the original application and within 30 calendar days after receipt of any supplementary information that is submitted.

(ii) When notifying the owner or operator that his/her application is not complete, the Administrator will specify the information needed to complete the application and provide notice of opportunity for the applicant to present, in writing, within 30 calendar days after he/she is notified of the incomplete application, additional information or arguments to the Administrator to enable further action on the application.

(3) Before denying any application for approval of construction or reconstruction, the Administrator will notify the applicant of the Administrator's intention to issue the denial together with—

(i) Notice of the information and findings on which the intended denial is based; and

(ii) Notice of opportunity for the applicant to present, in writing, within 30 calendar days after he/she is notified of the intended denial, additional information or arguments to the Administrator to enable further action on the application.

(4) A final determination to deny any application for approval will be in writing and will specify the grounds on which the denial is based. The final determination will be made within 60 calendar days of presentation of additional information or arguments (if the application is complete), or within 60 calendar days after the final date specified for presentation if no presentation is made.

(5) Neither the submission of an application for approval nor the Administrator's approval of construction or reconstruction shall—

(i) Relieve an owner or operator of legal responsibility for compliance with any applicable provisions of this part or with any other applicable Federal, State, or local requirement; or

(ii) Prevent the Administrator from implementing or enforcing this part or taking any other action under the Act.

(f) Approval of construction or reconstruction based on prior State preconstruction review.

(1) Preconstruction review procedures that a State utilizes for other purposes may also be utilized for purposes of this section if the procedures are substantially equivalent to those specified in this section. The Administrator will approve an application for construction or reconstruction specified in paragraphs (b)(3) and (d) of this section if the owner or operator of a new affected source or reconstructed affected source, who is subject to such requirement meets the following conditions:


(i) The owner or operator of the new affected source or reconstructed affected source has undergone a preconstruction review and approval process in the State in which the source is (or would be) located and has received a federally enforceable construction permit that contains a finding that the source will meet the relevant promulgated emission standard, if the source is properly built and operated.

(ii) Provide a statement from the State or other evidence (such as State regulations) that it considered the factors specified in paragraph (e)(1) of this section.

(2) The owner or operator must submit to the Administrator the request for approval of construction or reconstruction under this paragraph (f)(2) no later than the application deadline specified in paragraph (d)(1) of this section (see also §63.9(b)(2)). The owner or operator must include in the request information sufficient for the Administrator's determination. The Administrator will evaluate the owner or operator's request in accordance with the procedures specified in paragraph (e) of this section. The Administrator may request additional relevant information after the submittal of a request for approval of construction or reconstruction under this paragraph (f)(2).

§63.6 Compliance with standards and maintenance requirements.

(a) Applicability.

(1) The requirements in this section apply to the owner or operator of affected sources for which any relevant standard has been established pursuant to section 112 of the Act and the applicability of such requirements is set out in accordance with §63.1(a)(4) unless—

(i) The Administrator (or a State with an approved permit program) has granted an extension of compliance consistent with paragraph (i) of this section; or

(ii) The President has granted an exemption from compliance with any relevant standard in accordance with section 112(i)(4) of the Act.

(2) If an area source that otherwise would be subject to an emission standard or other requirement established under this part if it were a major source subsequently increases its emissions of hazardous air pollutants (or its potential to emit hazardous air pollutants) such that the source is a major source, such source shall be subject to the relevant emission standard or other requirement.

(b) Compliance dates for new and reconstructed sources.

(1) Except as specified in paragraphs (b)(3) and (4) of this section, the owner or operator of a new or reconstructed affected source for which construction or reconstruction commences after proposal of a relevant standard that has an initial startup before the effective date of a relevant standard established under this part pursuant to section 112(d), (f), or (h) of the Act must comply with such standard not later than the standard's effective date.

(2) Except as specified in paragraphs (b)(3) and (4) of this section, the owner or operator of a new or reconstructed affected source that has an initial startup after the effective date of a relevant standard established under this part pursuant to section 112(d), (f), or (h) of the Act must comply with such standard upon startup of the source.

(3) The owner or operator of an affected source for which construction or reconstruction is commenced after the proposal date of a relevant standard established under this part pursuant to section 112(d), 112(f), or 112(h) of the Act but before the effective date (that is, promulgation) of such standard shall comply with the relevant emission standard not later than the date 3 years after the effective date if:

(i) The promulgated standard (that is, the relevant standard) is more stringent than the proposed standard; for purposes of this paragraph, a finding that controls or compliance methods are “more stringent” must include control technologies or performance criteria and compliance or compliance assurance methods that are


different but are substantially equivalent to those required by the promulgated rule, as determined by the Administrator (or his or her authorized representative); and

(ii) The owner or operator complies with the standard as proposed during the 3-year period immediately after the effective date.

(4) The owner or operator of an affected source for which construction or reconstruction is commenced after the proposal date of a relevant standard established pursuant to section 112(d) of the Act but before the proposal date of a relevant standard established pursuant to section 112(f) shall not be required to comply with the section 112(f) emission standard until the date 10 years after the date construction or reconstruction is commenced, except that, if the section 112(f) standard is promulgated more than 10 years after construction or reconstruction is commenced, the owner or operator must comply with the standard as provided in paragraphs (b)(1) and (2) of this section.

(5) The owner or operator of a new source that is subject to the compliance requirements of paragraph (b)(3) or (4) of this section must notify the Administrator in accordance with §63.9(d)

(6) [Reserved]

(7) When an area source becomes a major source by the addition of equipment or operations that meet the definition of new affected source in the relevant standard, the portion of the existing facility that is a new affected source must comply with all requirements of that standard applicable to new sources. The source owner or operator must comply with the relevant standard upon startup.

(c) Compliance dates for existing sources. (1) After the effective date of a relevant standard established under this part pursuant to section 112(d) or 112(h) of the Act, the owner or operator of an existing source shall comply with such standard by the compliance date established by the Administrator in the applicable subpart(s) of this part. Except as otherwise provided for in section 112 of the Act, in no case will the compliance date established for an existing source in an applicable subpart of this part exceed 3 years after the effective date of such standard.

(2) If an existing source is subject to a standard established under this part pursuant to section 112(f) of the Act, the owner or operator must comply with the standard by the date 90 days after the standard's effective date, or by the date specified in an extension granted to the source by the Administrator under paragraph (i)(4)(ii) of this section, whichever is later.

(3)-(4) [Reserved]

(5) Except as provided in paragraph (b)(7) of this section, the owner or operator of an area source that increases its emissions of (or its potential to emit) hazardous air pollutants such that the source becomes a major source shall be subject to relevant standards for existing sources. Such sources must comply by the date specified in the standards for existing area sources that become major sources. If no such compliance date is specified in the standards, the source shall have a period of time to comply with the relevant emission standard that is equivalent to the compliance period specified in the relevant standard for existing sources in existence at the time the standard becomes effective.

(d) [Reserved]

(e) Operation and maintenance requirements. (1)(i) At all times, including periods of startup, shutdown, and malfunction, the owner or operator 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. During a period of startup, shutdown, or malfunction, this general duty to minimize emissions requires that the owner or operator reduce emissions from the affected source to the greatest extent which is consistent with safety and good air pollution control practices. The general duty to minimize emissions during a period of startup, shutdown, or malfunction does not require the owner or operator to achieve emission levels that would be required by the applicable standard at other times if this is not consistent with safety and good air pollution control practices, nor does it require the owner or operator to make any further efforts to reduce emissions if levels required by the applicable


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 (including the startup, shutdown, and malfunction plan required in paragraph (e)(3) of this section), review of operation and maintenance records, and inspection of the source.

(ii) Malfunctions must be corrected as soon as practicable after their occurrence. To the extent that an unexpected event arises during a startup, shutdown, or malfunction, an owner or operator must comply by minimizing emissions during such a startup, shutdown, and malfunction event consistent with safety and good air pollution control practices.

(iii) Operation and maintenance requirements established pursuant to section 112 of the Act are enforceable independent of emissions limitations or other requirements in relevant standards.

(2) [Reserved]

(3) Startup, shutdown, and malfunction plan.

(i) The owner or operator of an affected source must develop a written startup, shutdown, and malfunction plan that describes, in detail, procedures for operating and maintaining the source during periods of startup, shutdown, and malfunction; and a program of corrective action for malfunctioning process, air pollution control, and monitoring equipment used to comply with the relevant standard. The startup, shutdown, and malfunction plan does not need to address any scenario that would not cause the source to exceed an applicable emission limitation in the relevant standard. This plan must be developed by the owner or operator by the source's compliance date for that relevant standard. The purpose of the startup, shutdown, and malfunction plan is to—

(A) Ensure that, at all times, the owner or operator operates and maintains each affected source, including associated air pollution control and monitoring equipment, in a manner which satisfies the general duty to minimize emissions established by paragraph (e)(1)(i) of this section;

(B) Ensure that owners or operators are prepared to correct malfunctions as soon as practicable after their occurrence in order to minimize excess emissions of hazardous air pollutants; and

(C) Reduce the reporting burden associated with periods of startup, shutdown, and malfunction (including corrective action taken to restore malfunctioning process and air pollution control equipment to its normal or usual manner of operation).

(ii) [Reserved]

(iii) When actions taken by the owner or operator during a startup or shutdown (and the startup or shutdown causes the source to exceed any applicable emission limitation in the relevant emission standards), or malfunction (including actions taken to correct a malfunction) are consistent with the procedures specified in the affected source's startup, shutdown, and malfunction plan, the owner or operator must keep records for that event which demonstrate that the procedures specified in the plan were followed. These records may take the form of a “checklist,” or other effective form of recordkeeping that confirms conformance with the startup, shutdown, and malfunction plan and describes the actions taken for that event. In addition, the owner or operator must keep records of these events as specified in paragraph 63.10(b), including records of the occurrence and duration of each startup or shutdown (if the startup or shutdown causes the source to exceed any applicable emission limitation in the relevant emission standards), or malfunction of operation and each malfunction of the air pollution control and monitoring equipment. Furthermore, the owner or operator shall confirm that actions taken during the relevant reporting period during periods of startup, shutdown, and malfunction were consistent with the affected source's startup, shutdown and malfunction plan in the semiannual (or more frequent) startup, shutdown, and malfunction report required in §63.10(d)(5).


(iv) If an action taken by the owner or operator during a startup, shutdown, or malfunction (including an action taken to correct a malfunction) is not consistent with the procedures specified in the affected source's startup, shutdown, and malfunction plan, and the source exceeds any applicable emission limitation in the relevant emission standard, then the owner or operator must record the actions taken for that event and must report such actions within 2 working days after commencing actions inconsistent with the plan, followed by a letter within 7 working days after the end of the event, in accordance with §63.10(d)(5) (unless the owner or operator makes alternative reporting arrangements, in advance, with the Administrator).

(v) The owner or operator must maintain at the affected source a current startup, shutdown, and malfunction plan and must make the plan available upon request for inspection and copying by the Administrator. In addition, if the startup, shutdown, and malfunction plan is subsequently revised as provided in paragraph (e)(3)(viii) of this section, the owner or operator must maintain at the affected source each previous (i.e., superseded) version of the startup, shutdown, and malfunction plan, and must make each such previous version available for inspection and copying by the Administrator for a period of 5 years after revision of the plan. If at any time after adoption of a startup, shutdown, and malfunction plan the affected source ceases operation or is otherwise no longer subject to the provisions of this part, the owner or operator must retain a copy of the most recent plan for 5 years from the date the source ceases operation or is no longer subject to this part and must make the plan available upon request for inspection and copying by the Administrator. The Administrator may at any time request in writing that the owner or operator submit a copy of any startup, shutdown, and malfunction plan (or a portion thereof) which is maintained at the affected source or in the possession of the owner or operator. Upon receipt of such a request, the owner or operator must promptly submit a copy of the requested plan (or a portion thereof) to the Administrator. The owner or operator may elect to submit the required copy of any startup, shutdown, and malfunction plan to the Administrator in an electronic format. If the owner or operator claims that any portion of such a startup, shutdown, and malfunction plan is confidential business information entitled to protection from disclosure under section 114(c) of the Act or 40 CFR 2.301, the material which is claimed as confidential must be clearly designated in the submission.

(vi) To satisfy the requirements of this section to develop a startup, shutdown, and malfunction plan, the owner or operator may use the affected source's standard operating procedures (SOP) manual, or an Occupational Safety and Health Administration (OSHA) or other plan, provided the alternative plans meet all the requirements of this section and are made available for inspection or submitted when requested by the Administrator.

(vii) Based on the results of a determination made under paragraph (e)(1)(i) of this section, the Administrator may require that an owner or operator of an affected source make changes to the startup, shutdown, and malfunction plan for that source. The Administrator must require appropriate revisions to a startup, shutdown, and malfunction plan, if the Administrator finds that the plan:

(A) Does not address a startup, shutdown, or malfunction event that has occurred;

(B) Fails to provide for the operation of the source (including associated air pollution control and monitoring equipment) during a startup, shutdown, or malfunction event in a manner consistent with the general duty to minimize emissions established by paragraph (e)(1)(i) of this section;

(C) Does not provide adequate procedures for correcting malfunctioning process and/or air pollution control and monitoring equipment as quickly as practicable; or

(D) Includes an event that does not meet the definition of startup, shutdown, or malfunction listed in §63.2.

(viii) The owner or operator may periodically revise the startup, shutdown, and malfunction plan for the affected source as necessary to satisfy the requirements of this part or to reflect changes in equipment or procedures at the affected source. Unless the permitting authority provides otherwise, the owner or operator may make such revisions to the startup, shutdown, and malfunction plan without prior approval by the Administrator or the


permitting authority. However, each such revision to a startup, shutdown, and malfunction plan must be reported in the semiannual report required by §63.10(d)(5). If the startup, shutdown, and malfunction plan fails to address or inadequately addresses an event that meets the characteristics of a malfunction but was not included in the startup, shutdown, and malfunction plan at the time the owner or operator developed the plan, the owner or operator must revise the startup, shutdown, and malfunction plan within 45 days after the event to include detailed procedures for operating and maintaining the source during similar malfunction events and a program of corrective action for similar malfunctions of process or air pollution control and monitoring equipment. In the event that the owner or operator makes any revision to the startup, shutdown, and malfunction plan which alters the scope of the activities at the source which are deemed to be a startup, shutdown, or malfunction, or otherwise modifies the applicability of any emission limit, work practice requirement, or other requirement in a standard established under this part, the revised plan shall not take effect until after the owner or operator has provided a written notice describing the revision to the permitting authority.

(ix) The title V permit for an affected source must require that the owner or operator develop a startup, shutdown, and malfunction plan which conforms to the provisions of this part, but may do so by citing to the relevant subpart or subparagraphs of paragraph (e) of this section. However, any revisions made to the startup, shutdown, and malfunction plan in accordance with the procedures established by this part shall not be deemed to constitute permit revisions under part 70 or part 71 of this chapter and the elements of the startup, shutdown, and malfunction plan shall not be considered an applicable requirement as defined in §70.2 and §71.2 of this chapter. Moreover, none of the procedures specified by the startup, shutdown, and malfunction plan for an affected source shall be deemed to fall within the permit shield provision in section 504(f) of the Act.

(f) Compliance with nonopacity emission standards—

(1) Applicability. The non-opacity emission standards set forth in this part shall apply at all times except during periods of startup, shutdown, and malfunction, and as otherwise specified in an applicable subpart. If a startup, shutdown, or malfunction of one portion of an affected source does not affect the ability of particular emission points within other portions of the affected source to comply with the non-opacity emission standards set forth in this part, then that emission point must still be required to comply with the non-opacity emission standards and other applicable requirements.

(2) Methods for determining compliance.

(i) The Administrator will determine compliance with nonopacity emission standards in this part based on the results of performance tests conducted according to the procedures in §63.7, unless otherwise specified in an applicable subpart of this part.

(ii) The Administrator will determine compliance with nonopacity emission standards in this part by evaluation of an owner or operator's conformance with operation and maintenance requirements, including the evaluation of monitoring data, as specified in §63.6(e) and applicable subparts of this part.

(iii) If an affected source conducts performance testing at startup to obtain an operating permit in the State in which the source is located, the results of such testing may be used to demonstrate compliance with a relevant standard if—

(A) The performance test was conducted within a reasonable amount of time before an initial performance test is required to be conducted under the relevant standard;

(B) The performance test was conducted under representative operating conditions for the source;

(C) The performance test was conducted and the resulting data were reduced using EPA-approved test methods and procedures, as specified in §63.7(e) of this subpart; and


(D) The performance test was appropriately quality-assured, as specified in §63.7(c).

(iv) The Administrator will determine compliance with design, equipment, work practice, or operational emission standards in this part by review of records, inspection of the source, and other procedures specified in applicable subparts of this part.

(v) The Administrator will determine compliance with design, equipment, work practice, or operational emission standards in this part by evaluation of an owner or operator's conformance with operation and maintenance requirements, as specified in paragraph (e) of this section and applicable subparts of this part.

(3) Finding of compliance. The Administrator will make a finding concerning an affected source's compliance with a non-opacity emission standard, as specified in paragraphs (f)(1) and (2) of this section, upon obtaining all the compliance information required by the relevant standard (including the written reports of performance test results, monitoring results, and other information, if applicable), and information available to the Administrator pursuant to paragraph (e)(1)(i) of this section.

(g) Use of an alternative nonopacity emission standard.

(1) If, in the Administrator's judgment, an owner or operator of an affected source has established that an alternative means of emission limitation will achieve a reduction in emissions of a hazardous air pollutant from an affected source at least equivalent to the reduction in emissions of that pollutant from that source achieved under any design, equipment, work practice, or operational emission standard, or combination thereof, established under this part pursuant to section 112(h) of the Act, the Administrator will publish in the Federal Register a notice permitting the use of the alternative emission standard for purposes of compliance with the promulgated standard. Any Federal Register notice under this paragraph shall be published only after the public is notified and given the opportunity to comment. Such notice will restrict the permission to the stationary source(s) or category(ies) of sources from which the alternative emission standard will achieve equivalent emission reductions. The Administrator will condition permission in such notice on requirements to assure the proper operation and maintenance of equipment and practices required for compliance with the alternative emission standard and other requirements, including appropriate quality assurance and quality control requirements, that are deemed necessary.

(2) An owner or operator requesting permission under this paragraph shall, unless otherwise specified in an applicable subpart, submit a proposed test plan or the results of testing and monitoring in accordance with §63.7 and §63.8, a description of the procedures followed in testing or monitoring, and a description of pertinent conditions during testing or monitoring. Any testing or monitoring conducted to request permission to use an alternative nonopacity emission standard shall be appropriately quality assured and quality controlled, as specified in §63.7 and §63.8.

(3) The Administrator may establish general procedures in an applicable subpart that accomplish the requirements of paragraphs (g)(1) and (g)(2) of this section.

(h) Compliance with opacity and visible emission standards—

(1) Applicability. The opacity and visible emission standards set forth in this part must apply at all times except during periods of startup, shutdown, and malfunction, and as otherwise specified in an applicable subpart. If a startup, shutdown, or malfunction of one portion of an affected source does not affect the ability of particular emission points within other portions of the affected source to comply with the opacity and visible emission standards set forth in this part, then that emission point shall still be required to comply with the opacity and visible emission standards and other applicable requirements.

(2) Methods for determining compliance.

(i) The Administrator will determine compliance with opacity and visible emission standards in this part based on the results of the test method specified in an applicable subpart. Whenever a continuous opacity monitoring system (COMS) is required to be installed to determine compliance with numerical opacity emission standards in


this part, compliance with opacity emission standards in this part shall be determined by using the results from the COMS. Whenever an opacity emission test method is not specified, compliance with opacity emission standards in this part shall be determined by conducting observations in accordance with Test Method 9 in appendix A of part 60 of this chapter or the method specified in paragraph (h)(7)(ii) of this section. Whenever a visible emission test method is not specified, compliance with visible emission standards in this part shall be determined by conducting observations in accordance with Test Method 22 in appendix A of part 60 of this chapter.

(ii) [Reserved]

(iii) If an affected source undergoes opacity or visible emission testing at startup to obtain an operating permit in the State in which the source is located, the results of such testing may be used to demonstrate compliance with a relevant standard if—

(A) The opacity or visible emission test was conducted within a reasonable amount of time before a performance test is required to be conducted under the relevant standard;

(B) The opacity or visible emission test was conducted under representative operating conditions for the source;

(C) The opacity or visible emission test was conducted and the resulting data were reduced using EPA-approved test methods and procedures, as specified in §63.7(e); and

(D) The opacity or visible emission test was appropriately quality-assured, as specified in §63.7(c) of this section.

(3) [Reserved]

(4) Notification of opacity or visible emission observations. The owner or operator of an affected source shall notify the Administrator in writing of the anticipated date for conducting opacity or visible emission observations in accordance with §63.9(f), if such observations are required for the source by a relevant standard.

(5) Conduct of opacity or visible emission observations. When a relevant standard under this part includes an opacity or visible emission standard, the owner or operator of an affected source shall comply with the following:

(i) For the purpose of demonstrating initial compliance, opacity or visible emission observations shall be conducted concurrently with the initial performance test required in §63.7 unless one of the following conditions applies:

(A) If no performance test under §63.7 is required, opacity or visible emission observations shall be conducted within 60 days after achieving the maximum production rate at which a new or reconstructed source will be operated, but not later than 120 days after initial startup of the source, or within 120 days after the effective date of the relevant standard in the case of new sources that start up before the standard's effective date. If no performance test under §63.7 is required, opacity or visible emission observations shall be conducted within 120 days after the compliance date for an existing or modified source; or

(B) If visibility or other conditions prevent the opacity or visible emission observations from being conducted concurrently with the initial performance test required under §63.7, or within the time period specified in paragraph (h)(5)(i)(A) of this section, the source's owner or operator shall reschedule the opacity or visible emission observations as soon after the initial performance test, or time period, as possible, but not later than 30 days thereafter, and shall advise the Administrator of the rescheduled date. The rescheduled opacity or visible emission observations shall be conducted (to the extent possible) under the same operating conditions that existed during the initial performance test conducted under §63.7. The visible emissions observer shall determine whether visibility or other


conditions prevent the opacity or visible emission observations from being made concurrently with the initial performance test in accordance with procedures contained in Test Method 9 or Test Method 22 in appendix A of part 60 of this chapter.

(ii) For the purpose of demonstrating initial compliance, the minimum total time of opacity observations shall be 3 hours (30 6-minute averages) for the performance test or other required set of observations (e.g., for fugitive-type emission sources subject only to an opacity emission standard).

(iii) The owner or operator of an affected source to which an opacity or visible emission standard in this part applies shall conduct opacity or visible emission observations in accordance with the provisions of this section, record the results of the evaluation of emissions, and report to the Administrator the opacity or visible emission results in accordance with the provisions of §63.10(d).

(iv) [Reserved]

(v) Opacity readings of portions of plumes that contain condensed, uncombined water vapor shall not be used for purposes of determining compliance with opacity emission standards.

(6) Availability of records. The owner or operator of an affected source shall make available, upon request by the Administrator, such records that the Administrator deems necessary to determine the conditions under which the visual observations were made and shall provide evidence indicating proof of current visible observer emission certification.

(7) Use of a continuous opacity monitoring system.

(i) The owner or operator of an affected source required to use a continuous opacity monitoring system (COMS) shall record the monitoring data produced during a performance test required under §63.7 and shall furnish the Administrator a written report of the monitoring results in accordance with the provisions of §63.10(e)(4).

(ii) Whenever an opacity emission test method has not been specified in an applicable subpart, or an owner or operator of an affected source is required to conduct Test Method 9 observations (see appendix A of part 60 of this chapter), the owner or operator may submit, for compliance purposes, COMS data results produced during any performance test required under §63.7 in lieu of Method 9 data. If the owner or operator elects to submit COMS data for compliance with the opacity emission standard, he or she shall notify the Administrator of that decision, in writing, simultaneously with the notification under §63.7(b) of the date the performance test is scheduled to begin. Once the owner or operator of an affected source has notified the Administrator to that effect, the COMS data results will be used to determine opacity compliance during subsequent performance tests required under §63.7, unless the owner or operator notifies the Administrator in writing to the contrary not later than with the notification under §63.7(b) of the date the subsequent performance test is scheduled to begin.

(iii) For the purposes of determining compliance with the opacity emission standard during a performance test required under §63.7 using COMS data, the COMS data shall be reduced to 6-minute averages over the duration of the mass emission performance test.

(iv) The owner or operator of an affected source using a COMS for compliance purposes is responsible for demonstrating that he/she has complied with the performance evaluation requirements of §63.8(e), that the COMS has been properly maintained, operated, and data quality-assured, as specified in §63.8(c) and §63.8(d), and that the resulting data have not been altered in any way.

(v) Except as provided in paragraph (h)(7)(ii) of this section, the results of continuous monitoring by a COMS that indicate that the opacity at the time visual observations were made was not in excess of the emission standard are probative but not conclusive evidence of the actual opacity of an emission, provided that the affected source proves that, at the time of the alleged violation, the instrument used was properly maintained, as specified in


§63.8(c), and met Performance Specification 1 in appendix B of part 60 of this chapter, and that the resulting data have not been altered in any way.

(8) Finding of compliance. The Administrator will make a finding concerning an affected source's compliance with an opacity or visible emission standard upon obtaining all the compliance information required by the relevant standard (including the written reports of the results of the performance tests required by §63.7, the results of Test Method 9 or another required opacity or visible emission test method, the observer certification required by paragraph (h)(6) of this section, and the continuous opacity monitoring system results, whichever is/are applicable) and any information available to the Administrator needed to determine whether proper operation and maintenance practices are being used.

(9) Adjustment to an opacity emission standard.

(i) If the Administrator finds under paragraph (h)(8) of this section that an affected source is in compliance with all relevant standards for which initial performance tests were conducted under §63.7, but during the time such performance tests were conducted fails to meet any relevant opacity emission standard, the owner or operator of such source may petition the Administrator to make appropriate adjustment to the opacity emission standard for the affected source. Until the Administrator notifies the owner or operator of the appropriate adjustment, the relevant opacity emission standard remains applicable.

(ii) The Administrator may grant such a petition upon a demonstration by the owner or operator that—

(A) The affected source and its associated air pollution control equipment were operated and maintained in a manner to minimize the opacity of emissions during the performance tests;

(B) The performance tests were performed under the conditions established by the Administrator; and

(C) The affected source and its associated air pollution control equipment were incapable of being adjusted or operated to meet the relevant opacity emission standard.

(iii) The Administrator will establish an adjusted opacity emission standard for the affected source meeting the above requirements at a level at which the source will be able, as indicated by the performance and opacity tests, to meet the opacity emission standard at all times during which the source is meeting the mass or concentration emission standard. The Administrator will promulgate the new opacity emission standard in the Federal Register.

(iv) After the Administrator promulgates an adjusted opacity emission standard for an affected source, the owner or operator of such source shall be subject to the new opacity emission standard, and the new opacity emission standard shall apply to such source during any subsequent performance tests.

(i) Extension of compliance with emission standards.

(1) Until an extension of compliance has been granted by the Administrator (or a State with an approved permit program) under this paragraph, the owner or operator of an affected source subject to the requirements of this section shall comply with all applicable requirements of this part.

(2) Extension of compliance for early reductions and other reductions—

(i) Early reductions. Pursuant to section 112(i)(5) of the Act, if the owner or operator of an existing source demonstrates that the source has achieved a reduction in emissions of hazardous air pollutants in accordance with the provisions of subpart D of this part, the Administrator (or the State with an approved permit program) will grant the owner or operator an extension of compliance with specific requirements of this part, as specified in subpart D.

(ii) Other reductions. Pursuant to section 112(i)(6) of the Act, if the owner or operator of an existing source has installed best available control technology (BACT) (as defined in section 169(3) of the Act) or technology required


to meet a lowest achievable emission rate (LAER) (as defined in section 171 of the Act) prior to the promulgation of an emission standard in this part applicable to such source and the same pollutant (or stream of pollutants) controlled pursuant to the BACT or LAER installation, the Administrator will grant the owner or operator an extension of compliance with such emission standard that will apply until the date 5 years after the date on which such installation was achieved, as determined by the Administrator.

(3) Request for extension of compliance. Paragraphs (i)(4) through (i)(7) of this section concern requests for an extension of compliance with a relevant standard under this part (except requests for an extension of compliance under paragraph (i)(2)(i) of this section will be handled through procedures specified in subpart D of this part).

(4)(i)(A) The owner or operator of an existing source who is unable to comply with a relevant standard established under this part pursuant to section 112(d) of the Act may request that the Administrator (or a State, when the State has an approved part 70 permit program and the source is required to obtain a part 70 permit under that program, or a State, when the State has been delegated the authority to implement and enforce the emission standard for that source) grant an extension allowing the source up to 1 additional year to comply with the standard, if such additional period is necessary for the installation of controls. An additional extension of up to 3 years may be added for mining waste operations, if the 1-year extension of compliance is insufficient to dry and cover mining waste in order to reduce emissions of any hazardous air pollutant. The owner or operator of an affected source who has requested an extension of compliance under this paragraph and who is otherwise required to obtain a title V permit shall apply for such permit or apply to have the source's title V permit revised to incorporate the conditions of the extension of compliance. The conditions of an extension of compliance granted under this paragraph will be incorporated into the affected source's title V permit according to the provisions of part 70 or Federal title V regulations in this chapter (42 U.S.C. 7661), whichever are applicable.

(B) Any request under this paragraph for an extension of compliance with a relevant standard must be submitted in writing to the appropriate authority no later than 120 days prior to the affected source's compliance date (as specified in paragraphs (b) and (c) of this section), except as provided for in paragraph (i)(4)(i)(C) of this section. Nonfrivolous requests submitted under this paragraph will stay the applicability of the rule as to the emission points in question until such time as the request is granted or denied. A denial will be effective as of the date of denial. Emission standards established under this part may specify alternative dates for the submittal of requests for an extension of compliance if alternatives are appropriate for the source categories affected by those standards.

(C) An owner or operator may submit a compliance extension request after the date specified in paragraph (i)(4)(i)(B) of this section provided the need for the compliance extension arose after that date, and before the otherwise applicable compliance date and the need arose due to circumstances beyond reasonable control of the owner or operator. This request must include, in addition to the information required in paragraph (i)(6)(i) of this section, a statement of the reasons additional time is needed and the date when the owner or operator first learned of the problems. Nonfrivolous requests submitted under this paragraph will stay the applicability of the rule as to the emission points in question until such time as the request is granted or denied. A denial will be effective as of the original compliance date.

(ii) The owner or operator of an existing source unable to comply with a relevant standard established under this part pursuant to section 112(f) of the Act may request that the Administrator grant an extension allowing the source up to 2 years after the standard's effective date to comply with the standard. The Administrator may grant such an extension if he/she finds that such additional period is necessary for the installation of controls and that steps will be taken during the period of the extension to assure that the health of persons will be protected from imminent endangerment. Any request for an extension of compliance with a relevant standard under this paragraph must be submitted in writing to the Administrator not later than 90 calendar days after the effective date of the relevant standard.


(5) The owner or operator of an existing source that has installed BACT or technology required to meet LAER [as specified in paragraph (i)(2)(ii) of this section] prior to the promulgation of a relevant emission standard in this part may request that the Administrator grant an extension allowing the source 5 years from the date on which such installation was achieved, as determined by the Administrator, to comply with the standard. Any request for an extension of compliance with a relevant standard under this paragraph shall be submitted in writing to the Administrator not later than 120 days after the promulgation date of the standard. The Administrator may grant such an extension if he or she finds that the installation of BACT or technology to meet LAER controls the same pollutant (or stream of pollutants) that would be controlled at that source by the relevant emission standard.

(6)(i) The request for a compliance extension under paragraph (i)(4) of this section shall include the following information:

(A) A description of the controls to be installed to comply with the standard;

(B) A compliance schedule, including the date by which each step toward compliance will be reached. At a minimum, the list of dates shall include:

(1) The date by which on-site construction, installation of emission control equipment, or a process change is planned to be initiated; and

(2) The date by which final compliance is to be achieved.

(3) The date by which on-site construction, installation of emission control equipment, or a process change is to be completed; and

(4) The date by which final compliance is to be achieved;

(C)-(D)

(ii) The request for a compliance extension under paragraph (i)(5) of this section shall include all information needed to demonstrate to the Administrator's satisfaction that the installation of BACT or technology to meet LAER controls the same pollutant (or stream of pollutants) that would be controlled at that source by the relevant emission standard.

(7) Advice on requesting an extension of compliance may be obtained from the Administrator (or the State with an approved permit program).

(8) Approval of request for extension of compliance. Paragraphs (i)(9) through (i)(14) of this section concern approval of an extension of compliance requested under paragraphs (i)(4) through (i)(6) of this section.

(9) Based on the information provided in any request made under paragraphs (i)(4) through (i)(6) of this section, or other information, the Administrator (or the State with an approved permit program) may grant an extension of compliance with an emission standard, as specified in paragraphs (i)(4) and (i)(5) of this section.

(10) The extension will be in writing and will—

(i) Identify each affected source covered by the extension;

(ii) Specify the termination date of the extension;

(iii) Specify the dates by which steps toward compliance are to be taken, if appropriate;

(iv) Specify other applicable requirements to which the compliance extension applies (e.g., performance tests); and

(v)(A) Under paragraph (i)(4), specify any additional conditions that the Administrator (or the State) deems necessary to assure installation of the necessary controls and protection of the health of persons during the extension period; or


(B) Under paragraph (i)(5), specify any additional conditions that the Administrator deems necessary to assure the proper operation and maintenance of the installed controls during the extension period.

(11) The owner or operator of an existing source that has been granted an extension of compliance under paragraph (i)(10) of this section may be required to submit to the Administrator (or the State with an approved permit program) progress reports indicating whether the steps toward compliance outlined in the compliance schedule have been reached. The contents of the progress reports and the dates by which they shall be submitted will be specified in the written extension of compliance granted under paragraph (i)(10) of this section.

(12)(i) The Administrator (or the State with an approved permit program) will notify the owner or operator in writing of approval or intention to deny approval of a request for an extension of compliance within 30 calendar days after receipt of sufficient information to evaluate a request submitted under paragraph (i)(4)(i) or (i)(5) of this section. The Administrator (or the State) will notify the owner or operator in writing of the status of his/her application, that is, whether the application contains sufficient information to make a determination, within 30 calendar days after receipt of the original application and within 30 calendar days after receipt of any supplementary information that is submitted. The 30-day approval or denial period will begin after the owner or operator has been notified in writing that his/her application is complete.


(iii) Before denying any request for an extension of compliance, the Administrator (or the State with an approved permit program) will notify the owner or operator in writing of the Administrator's (or the State's) intention to issue the denial, together with—

(A) Notice of the information and findings on which the intended denial is based; and

(B) Notice of opportunity for the owner or operator to present in writing, within 15 calendar days after he/she is notified of the intended denial, additional information or arguments to the Administrator (or the State) before further action on the request.

(iv) The Administrator's final determination to deny any request for an extension will be in writing and will set forth the specific grounds on which the denial is based. The final determination will be made within 30 calendar days after presentation of additional information or argument (if the application is complete), or within 30 calendar days after the final date specified for the presentation if no presentation is made.

(13)(i) The Administrator will notify the owner or operator in writing of approval or intention to deny approval of a request for an extension of compliance within 30 calendar days after receipt of sufficient information to evaluate a request submitted under paragraph (i)(4)(ii) of this section. The 30-day approval or denial period will begin after the owner or operator has been notified in writing that his/her application is complete. The Administrator (or the State) will notify the owner or operator in writing of the status of his/her application, that is, whether the application contains sufficient information to make a determination, within 15 calendar days after receipt of the original application and within 15 calendar days after receipt of any supplementary information that is submitted.


(iii) Before denying any request for an extension of compliance, the Administrator will notify the owner or operator in writing of the Administrator's intention to issue the denial, together with—


(A) Notice of the information and findings on which the intended denial is based; and

(B) Notice of opportunity for the owner or operator to present in writing, within 15 calendar days after he/she is notified of the intended denial, additional information or arguments to the Administrator before further action on the request.

(iv) A final determination to deny any request for an extension will be in writing and will set forth the specific grounds on which the denial is based. The final determination will be made within 30 calendar days after presentation of additional information or argument (if the application is complete), or within 30 calendar days after the final date specified for the presentation if no presentation is made.

(14) The Administrator (or the State with an approved permit program) may terminate an extension of compliance at an earlier date than specified if any specification under paragraph (i)(10)(iii) or (iv) of this section is not met. Upon a determination to terminate, the Administrator will notify, in writing, the owner or operator of the Administrator's determination to terminate, together with:

(i) Notice of the reason for termination; and

(ii) Notice of opportunity for the owner or operator to present in writing, within 15 calendar days after he/she is notified of the determination to terminate, additional information or arguments to the Administrator before further action on the termination.

(iii) A final determination to terminate an extension of compliance will be in writing and will set forth the specific grounds on which the termination is based. The final determination will be made within 30 calendar days after presentation of additional information or arguments, or within 30 calendar days after the final date specified for the presentation if no presentation is made.

(15) [Reserved]

(16) The granting of an extension under this section shall not abrogate the Administrator's authority under section 114 of the Act.

(j) Exemption from compliance with emission standards. The President may exempt any stationary source from compliance with any relevant standard established pursuant to section 112 of the Act for a period of not more than 2 years if the President determines that the technology to implement such standard is not available and that it is in the national security interests of the United States to do so. An exemption under this paragraph may be extended for 1 or more additional periods, each period not to exceed 2 years.

§63.7 Performance testing requirements.

(a) Applicability and performance test dates.

(1) The applicability of this section is set out in §63.1(a)(4).

(2) Except as provided in paragraph (a)(4) of this section, if required to do performance testing by a relevant standard, and unless a waiver of performance testing is obtained under this section or the conditions of paragraph (c)(3)(ii)(B) of this section apply, the owner or operator of the affected source must perform such tests within 180 days of the compliance date for such source.

(i)-(viii) [Reserved]

(ix) Except as provided in paragraph (a)(4) of this section, when an emission standard promulgated under this part is more stringent than the standard proposed (see §63.6(b)(3)), the owner or operator of a new or reconstructed source subject to that standard for which construction or reconstruction is commenced between the proposal and promulgation dates of the standard shall comply with performance testing requirements


within 180 days after the standard's effective date, or within 180 days after startup of the source, whichever is later. If the promulgated standard is more stringent than the proposed standard, the owner or operator may choose to demonstrate compliance with either the proposed or the promulgated standard. If the owner or operator chooses to comply with the proposed standard initially, the owner or operator shall conduct a second performance test within 3 years and 180 days after the effective date of the standard, or after startup of the source, whichever is later, to demonstrate compliance with the promulgated standard.

(3) The Administrator may require an owner or operator to conduct performance tests at the affected source at any other time when the action is authorized by section 114 of the Act.

(4) If a force majeure is about to occur, occurs, or has occurred for which the affected owner or operator intends to assert a claim of force majeure:

(i) The owner or operator shall notify the Administrator, in writing as soon as practicable following the date the owner or operator first knew, or through due diligence should have known that the event may cause or caused a delay in testing beyond the regulatory deadline specified in paragraph (a)(2) or (a)(3) of this section, or elsewhere in this part, but the notification must occur before the performance test deadline unless the initial force majeure or a subsequent force majeure event delays the notice, and in such cases, the notification shall occur as soon as practicable.

(ii) The owner or operator shall provide to the Administrator a written description of the force majeure event and a rationale for attributing the delay in testing beyond the regulatory deadline to the force majeure; describe the measures taken or to be taken to minimize the delay; and identify a date by which the owner or operator proposes to conduct the performance test. The performance test shall be conducted as soon as practicable after the force majeure occurs.

(iii) The decision as to whether or not to grant an extension to the performance test deadline is solely within the discretion of the Administrator. The Administrator will notify the owner or operator in writing of approval or disapproval of the request for an extension as soon as practicable.

(iv) Until an extension of the performance test deadline has been approved by the Administrator under paragraphs (a)(4)(i), (a)(4)(ii), and (a)(4)(iii) of this section, the owner or operator of the affected facility remains strictly subject to the requirements of this part.

(b) Notification of performance test.

(1) The owner or operator of an affected source must notify the Administrator in writing of his or her intention to conduct a performance test at least 60 calendar days before the performance test is initially scheduled to begin to allow the Administrator, upon request, to review an approve the site-specific test plan required under paragraph (c) of this section and to have an observer present during the test.

(2) In the event the owner or operator is unable to conduct the performance test on the date specified in the notification requirement specified in paragraph (b)(1) of this section due to unforeseeable circumstances beyond his or her control, the owner or operator must notify the Administrator as soon as practicable and without delay prior to the scheduled performance test date and specify the date when the performance test is rescheduled. This notification of delay in conducting the performance test shall not relieve the owner or operator of legal responsibility for compliance with any other applicable provisions of this part or with any other applicable Federal, State, or local requirement, nor will it prevent the Administrator from implementing or enforcing this part or taking any other action under the Act.

(c) Quality assurance program.

(1) The results of the quality assurance program required in this paragraph will be considered by the Administrator when he/she determines the validity of a performance test.


(2)(i) Submission of site-specific test plan. Before conducting a required performance test, the owner or operator of an affected source shall develop and, if requested by the Administrator, shall submit a site-specific test plan to the Administrator for approval. The test plan shall include a test program summary, the test schedule, data quality objectives, and both an internal and external quality assurance (QA) program. Data quality objectives are the pretest expectations of precision, accuracy, and completeness of data.

(ii) The internal QA program shall include, at a minimum, the activities planned by routine operators and analysts to provide an assessment of test data precision; an example of internal QA is the sampling and analysis of replicate samples.

(iii) The performance testing shall include a test method performance audit (PA) during the performance test. The PAs consist of blind audit samples supplied by an accredited audit sample provider and analyzed during the performance test in order to provide a measure of test data bias. Gaseous audit samples are designed to audit the performance of the sampling system as well as the analytical system and must be collected by the sampling system during the compliance test just as the compliance samples are collected. If a liquid or solid audit sample is designed to audit the sampling system, it must also be collected by the sampling system during the compliance test. If multiple sampling systems or sampling trains are used during the compliance test for any of the test methods, the tester is only required to use one of the sampling systems per method to collect the audit sample. The audit sample must be analyzed by the same analyst using the same analytical reagents and analytical system and at the same time as the compliance samples. Retests are required when there is a failure to produce acceptable results for an audit sample. However, if the audit results do not affect the compliance or noncompliance status of the affected facility, the compliance authority may waive the reanalysis requirement, further audits, or retests and accept the results of the compliance test. Acceptance of the test results shall constitute a waiver of the reanalysis requirement, further audits, or retests. The compliance authority may also use the audit sample failure and the compliance test results as evidence to determine the compliance or noncompliance status of the affected facility. A blind audit sample is a sample whose value is known only to the sample provider and is not revealed to the tested facility until after they report the measured value of the audit sample. For pollutants that exist in the gas phase at ambient temperature, the audit sample shall consist of an appropriate concentration of the pollutant in air or nitrogen that can be introduced into the sampling system of the test method at or near the same entry point as a sample from the emission source. If no gas phase audit samples are available, an acceptable alternative is a sample of the pollutant in the same matrix that would be produced when the sample is recovered from the sampling system as required by the test method. For samples that exist only in a liquid or solid form at ambient temperature, the audit sample shall consist of an appropriate concentration of the pollutant in the same matrix that would be produced when the sample is recovered from the sampling system as required by the test method. An accredited audit sample provider (AASP) is an organization that has been accredited to prepare audit samples by an independent, third party accrediting body.

(A) The source owner, operator, or representative of the tested facility shall obtain an audit sample, if commercially available, from an AASP for each test method used for regulatory compliance purposes. No audit samples are required for the following test methods: Methods 3A and 3C of appendix A-3 of part 60 of this chapter; Methods 6C, 7E, 9, and 10 of appendix A-4 of part 60; Methods 18 and 19 of appendix A-6 of part 60; Methods 20, 22, and 25A of appendix A-7 of part 60; Methods 30A and 30B of appendix A-8 of part 60; and Methods 303, 318, 320, and 321 of appendix A of this part. If multiple sources at a single facility are tested during a compliance test event, only one audit sample is required for each method used during a compliance test. The compliance authority responsible for the compliance test may waive the requirement to include an audit sample if they believe that an audit sample is not necessary. “Commercially available” means that two or more independent AASPs have blind audit samples available for purchase. If the source owner, operator, or representative cannot find an audit sample for a specific method, the owner, operator, or representative shall consult the EPA Web site at the following URL, www.epa.gov/ttn/emc, to confirm whether there is a source that can supply


an audit sample for that method. If the EPA Web site does not list an available audit sample at least 60 days prior to the beginning of the compliance test, the source owner, operator, or representative shall not be required to include an audit sample as part of the quality assurance program for the compliance test. When ordering an audit sample, the source owner, operator, or representative shall give the sample provider an estimate for the concentration of each pollutant that is emitted by the source or the estimated concentration of each pollutant based on the permitted level and the name, address, and phone number of the compliance authority. The source owner, operator, or representative shall report the results for the audit sample along with a summary of the emission test results for the audited pollutant to the compliance authority and shall report the results of the audit sample to the AASP. The source owner, operator, or representative shall make both reports at the same time and in the same manner or shall report to the compliance authority first and then report to the AASP. If the method being audited is a method that allows the samples to be analyzed in the field and the tester plans to analyze the samples in the field, the tester may analyze the audit samples prior to collecting the emission samples provided a representative of the compliance authority is present at the testing site. The tester may request, and the compliance authority may grant, a waiver to the requirement that a representative of the compliance authority must be present at the testing site during the field analysis of an audit sample. The source owner, operator, or representative may report the results of the audit sample to the compliance authority and then report the results of the audit sample to the AASP prior to collecting any emission samples. The test protocol and final test report shall document whether an audit sample was ordered and utilized and the pass/fail results as applicable.

(B) An AASP shall have and shall prepare, analyze, and report the true value of audit samples in accordance with a written technical criteria document that describes how audit samples will be prepared and distributed in a manner that will ensure the integrity of the audit sample program. An acceptable technical criteria document shall contain standard operating procedures for all of the following operations:

(1) Preparing the sample;

(2) Confirming the true concentration of the sample;

(3) Defining the acceptance limits for the results from a well qualified tester. This procedure must use well established statistical methods to analyze historical results from well qualified testers. The acceptance limits shall be set so that there is 95 percent confidence that 90 percent of well qualified labs will produce future results that are within the acceptance limit range;

(4) Providing the opportunity for the compliance authority to comment on the selected concentration level for an audit sample;

(5) Distributing the sample to the user in a manner that guarantees that the true value of the sample is unknown to the user;

(6) Recording the measured concentration reported by the user and determining if the measured value is within acceptable limits;

(7) Reporting the results from each audit sample in a timely manner to the compliance authority and to the source owner, operator, or representative by the AASP. The AASP shall make both reports at the same time and in the same manner or shall report to the compliance authority first and then report to the source owner, operator, or representative. The results shall include the name of the facility tested, the date on which the compliance test was conducted, the name of the company performing the sample collection, the name of the company that analyzed the compliance samples including the audit sample, the measured


result for the audit sample, and whether the testing company passed or failed the audit. The AASP shall report the true value of the audit sample to the compliance authority. The AASP may report the true value to the source owner, operator, or representative if the AASP's operating plan ensures that no laboratory will receive the same audit sample twice.

(8) Evaluating the acceptance limits of samples at least once every two years to determine in consultation with the voluntary consensus standard body if they should be changed.

(9) Maintaining a database, accessible to the compliance authorities, of results from the audit that shall include the name of the facility tested, the date on which the compliance test was conducted, the name of the company performing the sample collection, the name of the company that analyzed the compliance samples including the audit sample, the measured result for the audit sample, the true value of the audit sample, the acceptance range for the measured value, and whether the testing company passed or failed the audit.

(C) The accrediting body shall have a written technical criteria document that describes how it will ensure that the AASP is operating in accordance with the AASP technical criteria document that describes how audit samples are to be prepared and distributed. This document shall contain standard operating procedures for all of the following operations:

(1) Checking audit samples to confirm their true value as reported by the AASP.

(2) Performing technical systems audits of the AASP's facilities and operating procedures at least once every two years.

(3) Providing standards for use by the voluntary consensus standard body to approve the accrediting body that will accredit the audit sample providers.

(D) The technical criteria documents for the accredited sample providers and the accrediting body shall be developed through a public process guided by a voluntary consensus standards body (VCSB). The VCSB shall operate in accordance with the procedures and requirements in the Office of Management and Budget Circular A-119. A copy of Circular A-119 is available upon request by writing the Office of Information and Regulatory Affairs, Office of Management and Budget, 725 17th Street, NW., Washington, DC 20503, by calling (202) 395-6880 or downloading online at http://standards.gov/standards_gov/a119.cfm. The VCSB shall approve all accrediting bodies. The Administrator will review all technical criteria documents. If the technical criteria documents do not meet the minimum technical requirements in paragraphs (c)(2)(iii)(B) through (C) of this section, the technical criteria documents are not acceptable and the proposed audit sample program is not capable of producing audit samples of sufficient quality to be used in a compliance test. All acceptable technical criteria documents shall be posted on the EPA Web site at the following URL, http://www.epa.gov/ttn/emc.

(iv) The owner or operator of an affected source shall submit the site-specific test plan to the Administrator upon the Administrator's request at least 60 calendar days before the performance test is scheduled to take place, that is, simultaneously with the notification of intention to conduct a performance test required under paragraph (b) of this section, or on a mutually agreed upon date.

(v) The Administrator may request additional relevant information after the submittal of a site-specific test plan.

(3) Approval of site-specific test plan.

(i) The Administrator will notify the owner or operator of approval or intention to deny approval of the site-specific test plan (if review of the site-specific test plan is requested) within 30 calendar days after receipt of the original plan and within 30 calendar days after receipt of any supplementary information that is submitted


under paragraph (c)(3)(i)(B) of this section. Before disapproving any site-specific test plan, the Administrator will notify the applicant of the Administrator's intention to disapprove the plan together with—

(A) Notice of the information and findings on which the intended disapproval is based; and

(B) Notice of opportunity for the owner or operator to present, within 30 calendar days after he/she is notified of the intended disapproval, additional information to the Administrator before final action on the plan.

(ii) In the event that the Administrator fails to approve or disapprove the site-specific test plan within the time period specified in paragraph (c)(3)(i) of this section, the following conditions shall apply:

(A) If the owner or operator intends to demonstrate compliance using the test method(s) specified in the relevant standard or with only minor changes to those tests methods (see paragraph (e)(2)(i) of this section), the owner or operator must conduct the performance test within the time specified in this section using the specified method(s);

(B) If the owner or operator intends to demonstrate compliance by using an alternative to any test method specified in the relevant standard, the owner or operator is authorized to conduct the performance test using an alternative test method after the Administrator approves the use of the alternative method when the Administrator approves the site-specific test plan (if review of the site-specific test plan is requested) or after the alternative method is approved (see paragraph (f) of this section). However, the owner or operator is authorized to conduct the performance test using an alternative method in the absence of notification of approval 45 days after submission of the site-specific test plan or request to use an alternative method. The owner or operator is authorized to conduct the performance test within 60 calendar days after he/she is authorized to demonstrate compliance using an alternative test method. Notwithstanding the requirements in the preceding three sentences, the owner or operator may proceed to conduct the performance test as required in this section (without the Administrator's prior approval of the site-specific test plan) if he/she subsequently chooses to use the specified testing and monitoring methods instead of an alternative.

(iii) Neither the submission of a site-specific test plan for approval, nor the Administrator's approval or disapproval of a plan, nor the Administrator's failure to approve or disapprove a plan in a timely manner shall—

(A) Relieve an owner or operator of legal responsibility for compliance with any applicable provisions of this part or with any other applicable Federal, State, or local requirement; or

(B) Prevent the Administrator from implementing or enforcing this part or taking any other action under the Act.

(d) Performance testing facilities. If required to do performance testing, the owner or operator of each new source and, at the request of the Administrator, the owner or operator of each existing source, shall provide performance testing facilities as follows:

(1) Sampling ports adequate for test methods applicable to such source. This includes:

(i) Constructing the air pollution control system such that volumetric flow rates and pollutant emission rates can be accurately determined by applicable test methods and procedures; and

(ii) Providing a stack or duct free of cyclonic flow during performance tests, as demonstrated by applicable test methods and procedures;

(2) Safe sampling platform(s);

(3) Safe access to sampling platform(s);


(4) Utilities for sampling and testing equipment; and

(5) Any other facilities that the Administrator deems necessary for safe and adequate testing of a source.

(e) Conduct of performance tests.

(1) Performance tests shall be conducted under such conditions as the Administrator specifies to the owner or operator based on representative performance (i.e., performance based on normal operating conditions) of the affected source. Operations during periods of startup, shutdown, and malfunction shall not constitute representative conditions for the purpose of a performance test, nor shall emissions in excess of the level of the relevant standard during periods of startup, shutdown, and malfunction be considered a violation of the relevant standard unless otherwise specified in the relevant standard or a determination of noncompliance is made under §63.6(e). Upon request, the owner or operator shall make available to the Administrator such records as may be necessary to determine the conditions of performance tests.

(2) Performance tests shall be conducted and data shall be reduced in accordance with the test methods and procedures set forth in this section, in each relevant standard, and, if required, in applicable appendices of parts 51, 60, 61, and 63 of this chapter unless the Administrator—

(i) Specifies or approves, in specific cases, the use of a test method with minor changes in methodology (see definition in §63.90(a)). Such changes may be approved in conjunction with approval of the site-specific test plan (see paragraph (c) of this section); or

(ii) Approves the use of an intermediate or major change or alternative to a test method (see definitions in §63.90(a)), the results of which the Administrator has determined to be adequate for indicating whether a specific affected source is in compliance; or

(iii) Approves shorter sampling times or smaller sample volumes when necessitated by process variables or other factors; or

(iv) Waives the requirement for performance tests because the owner or operator of an affected source has demonstrated by other means to the Administrator's satisfaction that the affected source is in compliance with the relevant standard.

(3) Unless otherwise specified in a relevant standard or test method, each performance test shall consist of three separate runs using the applicable test method. Each run shall be conducted for the time and under the conditions specified in the relevant standard. For the purpose of determining compliance with a relevant standard, the arithmetic mean of the results of the three runs shall apply. Upon receiving approval from the Administrator, results of a test run may be replaced with results of an additional test run in the event that—

(i) A sample is accidentally lost after the testing team leaves the site; or

(ii) Conditions occur in which one of the three runs must be discontinued because of forced shutdown; or

(iii) Extreme meteorological conditions occur; or

(iv) Other circumstances occur that are beyond the owner or operator's control.

(4) Nothing in paragraphs (e)(1) through (e)(3) of this section shall be construed to abrogate the Administrator's authority to require testing under section 114 of the Act.

(f) Use of an alternative test method—

(1)General. Until authorized to use an intermediate or major change or alternative to a test method, the owner or operator of an affected source remains subject to the requirements of this section and the relevant standard.

(2) The owner or operator of an affected source required to do performance testing by a relevant standard may use an alternative test method from that specified in the standard provided that the owner or operator—


(i) Notifies the Administrator of his or her intention to use an alternative test method at least 60 days before the performance test is scheduled to begin;

(ii) Uses Method 301 in appendix A of this part to validate the alternative test method. This may include the use of specific procedures of Method 301 if use of such procedures are sufficient to validate the alternative test method; and

(iii) Submits the results of the Method 301 validation process along with the notification of intention and the justification for not using the specified test method. The owner or operator may submit the information required in this paragraph well in advance of the deadline specified in paragraph (f)(2)(i) of this section to ensure a timely review by the Administrator in order to meet the performance test date specified in this section or the relevant standard.

(3) The Administrator will determine whether the owner or operator's validation of the proposed alternative test method is adequate and issue an approval or disapproval of the alternative test method. If the owner or operator intends to demonstrate compliance by using an alternative to any test method specified in the relevant standard, the owner or operator is authorized to conduct the performance test using an alternative test method after the Administrator approves the use of the alternative method. However, the owner or operator is authorized to conduct the performance test using an alternative method in the absence of notification of approval/disapproval 45 days after submission of the request to use an alternative method and the request satisfies the requirements in paragraph (f)(2) of this section. The owner or operator is authorized to conduct the performance test within 60 calendar days after he/she is authorized to demonstrate compliance using an alternative test method. Notwithstanding the requirements in the preceding three sentences, the owner or operator may proceed to conduct the performance test as required in this section (without the Administrator's prior approval of the site-specific test plan) if he/she subsequently chooses to use the specified testing and monitoring methods instead of an alternative.

(4) If the Administrator finds reasonable grounds to dispute the results obtained by an alternative test method for the purposes of demonstrating compliance with a relevant standard, the Administrator may require the use of a test method specified in a relevant standard.

(5) If the owner or operator uses an alternative test method for an affected source during a required performance test, the owner or operator of such source shall continue to use the alternative test method for subsequent performance tests at that affected source until he or she receives approval from the Administrator to use another test method as allowed under §63.7(f).

(6) Neither the validation and approval process nor the failure to validate an alternative test method shall abrogate the owner or operator's responsibility to comply with the requirements of this part.

(g) Data analysis, recordkeeping, and reporting.

(1) Unless otherwise specified in a relevant standard or test method, or as otherwise approved by the Administrator in writing, results of a performance test shall include the analysis of samples, determination of emissions, and raw data. A performance test is “completed” when field sample collection is terminated. The owner or operator of an affected source shall report the results of the performance test to the Administrator before the close of business on the 60th day following the completion of the performance test, unless specified otherwise in a relevant standard or as approved otherwise in writing by the Administrator (see §63.9(i)). The results of the performance test shall be submitted as part of the notification of compliance status required under §63.9(h). Before a title V permit has been issued to the owner or operator of an affected source, the owner or operator shall send the results of the performance test to the Administrator. After a title V permit has been issued to the owner or operator of an affected source, the owner or operator shall send the results of the performance test to the appropriate permitting authority.


(2) Contents of report (electronic or paper submitted copy). Unless otherwise specified in a relevant standard or test method, or as otherwise approved by the Administrator in writing, the report for a performance test shall include the elements identified in paragraphs (g)(2)(i) through (vi) of this section.

(i) General identification information for the facility including a mailing address, the physical address, the owner or operator or responsible official (where applicable) and his/her email address, and the appropriate Federal Registry System (FRS) number for the facility.

(ii) Purpose of the test including the applicable regulation requiring the test, the pollutant(s) and other parameters being measured, the applicable emission standard, and any process parameter component, and a brief process description.

(iii) Description of the emission unit tested including fuel burned, control devices, and vent characteristics; the appropriate source classification code (SCC); the permitted maximum process rate (where applicable); and the sampling location.

(iv) Description of sampling and analysis procedures used and any modifications to standard procedures, quality assurance procedures and results, record of process operating conditions that demonstrate the applicable test conditions are met, and values for any operating parameters for which limits were being set during the test.

(v) Where a test method requires you record or report, the following shall be included in your report: Record of preparation of standards, record of calibrations, raw data sheets for field sampling, raw data sheets for field and laboratory analyses, chain-of-custody documentation, and example calculations for reported results.

(vi) Identification of the company conducting the performance test including the primary office address, telephone number, and the contact for this test including his/her email address.

(3) For a minimum of 5 years after a performance test is conducted, the owner or operator shall retain and make available, upon request, for inspection by the Administrator the records or results of such performance test and other data needed to determine emissions from an affected source.

(h) Waiver of performance tests.

(1) Until a waiver of a performance testing requirement has been granted by the Administrator under this paragraph, the owner or operator of an affected source remains subject to the requirements of this section.

(2) Individual performance tests may be waived upon written application to the Administrator if, in the Administrator's judgment, the source is meeting the relevant standard(s) on a continuous basis, or the source is being operated under an extension of compliance, or the owner or operator has requested an extension of compliance and the Administrator is still considering that request.

(3) Request to waive a performance test.

(i) If a request is made for an extension of compliance under §63.6(i), the application for a waiver of an initial performance test shall accompany the information required for the request for an extension of compliance. If no extension of compliance is requested or if the owner or operator has requested an extension of compliance and the Administrator is still considering that request, the application for a waiver of an initial performance test shall be submitted at least 60 days before the performance test if the site-specific test plan under paragraph (c) of this section is not submitted.

(ii) If an application for a waiver of a subsequent performance test is made, the application may accompany any required compliance progress report, compliance status report, or excess emissions and continuous monitoring system performance report [such as those required under §63.6(i), §63.9(h), and §63.10(e) or specified in a relevant standard or in the source's title V permit], but it shall be submitted at least 60 days before the performance test if the site-specific test plan required under paragraph (c) of this section is not submitted.


(iii) Any application for a waiver of a performance test shall include information justifying the owner or operator's request for a waiver, such as the technical or economic infeasibility, or the impracticality, of the affected source performing the required test.

(4) Approval of request to waive performance test. The Administrator will approve or deny a request for a waiver of a performance test made under paragraph (h)(3) of this section when he/she—

(i) Approves or denies an extension of compliance under §63.6(i)(8); or

(ii) Approves or disapproves a site-specific test plan under §63.7(c)(3); or

(iii) Makes a determination of compliance following the submission of a required compliance status report or excess emissions and continuous monitoring systems performance report; or

(iv) Makes a determination of suitable progress towards compliance following the submission of a compliance progress report, whichever is applicable.

(5) Approval of any waiver granted under this section shall not abrogate the Administrator's authority under the Act or in any way prohibit the Administrator from later canceling the waiver. The cancellation will be made only after notice is given to the owner or operator of the affected source.

§63.8 Monitoring requirements.

(a) Applicability.


(2) For the purposes of this part, all CMS required under relevant standards shall be subject to the provisions of this section upon promulgation of performance specifications for CMS as specified in the relevant standard or otherwise by the Administrator.

(3) [Reserved]

(4) Additional monitoring requirements for control devices used to comply with provisions in relevant standards of this part are specified in §63.11.

(b) Conduct of monitoring.

(1) Monitoring shall be conducted as set forth in this section and the relevant standard(s) unless the Administrator—

(i) Specifies or approves the use of minor changes in methodology for the specified monitoring requirements and procedures (see §63.90(a) for definition); or

(ii) Approves the use of an intermediate or major change or alternative to any monitoring requirements or procedures (see §63.90(a) for definition).

(iii) Owners or operators with flares subject to §63.11(b) are not subject to the requirements of this section unless otherwise specified in the relevant standard.

(2)(i) When the emissions from two or more affected sources are combined before being released to the atmosphere, the owner or operator may install an applicable CMS for each emission stream or for the combined emissions streams, provided the monitoring is sufficient to demonstrate compliance with the relevant standard.

(ii) If the relevant standard is a mass emission standard and the emissions from one affected source are released to the atmosphere through more than one point, the owner or operator must install an applicable CMS at each emission point unless the installation of fewer systems is—

(A) Approved by the Administrator; or


(B) Provided for in a relevant standard (e.g., instead of requiring that a CMS be installed at each emission point before the effluents from those points are channeled to a common control device, the standard specifies that only one CMS is required to be installed at the vent of the control device).

(3) When more than one CMS is used to measure the emissions from one affected source (e.g., multiple breechings, multiple outlets), the owner or operator shall report the results as required for each CMS. However, when one CMS is used as a backup to another CMS, the owner or operator shall report the results from the CMS used to meet the monitoring requirements of this part. If both such CMS are used during a particular reporting period to meet the monitoring requirements of this part, then the owner or operator shall report the results from each CMS for the relevant compliance period.

(c) Operation and maintenance of continuous monitoring systems.

(1) The owner or operator of an affected source shall maintain and operate each CMS as specified in this section, or in a relevant standard, and in a manner consistent with good air pollution control practices. (i) The owner or operator of an affected source must maintain and operate each CMS as specified in §63.6(e)(1).

(ii) The owner or operator must keep the necessary parts for routine repairs of the affected CMS equipment readily available.

(iii) The owner or operator of an affected source must develop a written startup, shutdown, and malfunction plan for CMS as specified in §63.6(e)(3).

(2)(i) All CMS must be installed such that representative measures of emissions or process parameters from the affected source are obtained. In addition, CEMS must be located according to procedures contained in the applicable performance specification(s).

(ii) Unless the individual subpart states otherwise, the owner or operator must ensure the read out (that portion of the CMS that provides a visual display or record), or other indication of operation, from any CMS required for compliance with the emission standard is readily accessible on site for operational control or inspection by the operator of the equipment.

(3) All CMS shall be installed, operational, and the data verified as specified in the relevant standard either prior to or in conjunction with conducting performance tests under §63.7. Verification of operational status shall, at a minimum, include completion of the manufacturer's written specifications or recommendations for installation, operation, and calibration of the system.

(4) Except for system breakdowns, out-of-control periods, repairs, maintenance periods, calibration checks, and zero (low-level) and high-level calibration drift adjustments, all CMS, including COMS and CEMS, shall be in continuous operation and shall meet minimum frequency of operation requirements as follows:

(i) All COMS shall complete a minimum of one cycle of sampling and analyzing for each successive 10-second period and one cycle of data recording for each successive 6-minute period.

(ii) All CEMS for measuring emissions other than opacity shall complete a minimum of one cycle of operation (sampling, analyzing, and data recording) for each successive 15-minute period.

(5) Unless otherwise approved by the Administrator, minimum procedures for COMS shall include a method for producing a simulated zero opacity condition and an upscale (high-level) opacity condition using a certified neutral density filter or other related technique to produce a known obscuration of the light beam. Such procedures shall provide a system check of all the analyzer's internal optical surfaces and all electronic circuitry, including the lamp and photodetector assembly normally used in the measurement of opacity.

(6) The owner or operator of a CMS that is not a CPMS, which is installed in accordance with the provisions of this part and the applicable CMS performance specification(s), must check the zero (low-level) and high-level calibration drifts at


least once daily in accordance with the written procedure specified in the performance evaluation plan developed under paragraphs (e)(3)(i) and (ii) of this section. The zero (low-level) and high-level calibration drifts must be adjusted, at a minimum, whenever the 24-hour zero (low-level) drift exceeds two times the limits of the applicable performance specification(s) specified in the relevant standard. The system shall allow the amount of excess zero (low-level) and high-level drift measured at the 24-hour interval checks to be recorded and quantified whenever specified. For COMS, all optical and instrumental surfaces exposed to the effluent gases must be cleaned prior to performing the zero (low-level) and high-level drift adjustments; the optical surfaces and instrumental surfaces must be cleaned when the cumulative automatic zero compensation, if applicable, exceeds 4 percent opacity. The CPMS must be calibrated prior to use for the purposes of complying with this section. The CPMS must be checked daily for indication that the system is responding. If the CPMS system includes an internal system check, results must be recorded and checked daily for proper operation.

(7)(i) A CMS is out of control if—

(A) The zero (low-level), mid-level (if applicable), or high-level calibration drift (CD) exceeds two times the applicable CD specification in the applicable performance specification or in the relevant standard; or

(B) The CMS fails a performance test audit (e.g., cylinder gas audit), relative accuracy audit, relative accuracy test audit, or linearity test audit; or

(C) The COMS CD exceeds two times the limit in the applicable performance specification in the relevant standard.

(ii) When the CMS is out of control, the owner or operator of the affected source shall take the necessary corrective action and shall repeat all necessary tests which indicate that the system is out of control. The owner or operator shall take corrective action and conduct retesting until the performance requirements are below the applicable limits. The beginning of the out-of-control period is the hour the owner or operator conducts a performance check (e.g., calibration drift) that indicates an exceedance of the performance requirements established under this part. The end of the out-of-control period is the hour following the completion of corrective action and successful demonstration that the system is within the allowable limits. During the period the CMS is out of control, recorded data shall not be used in data averages and calculations, or to meet any data availability requirement established under this part.

(8) The owner or operator of a CMS that is out of control as defined in paragraph (c)(7) of this section shall submit all information concerning out-of-control periods, including start and end dates and hours and descriptions of corrective actions taken, in the excess emissions and continuous monitoring system performance report required in §63.10(e)(3).

(d) Quality control program.

(1) The results of the quality control program required in this paragraph will be considered by the Administrator when he/she determines the validity of monitoring data.

(2) The owner or operator of an affected source that is required to use a CMS and is subject to the monitoring requirements of this section and a relevant standard shall develop and implement a CMS quality control program. As part of the quality control program, the owner or operator shall develop and submit to the Administrator for approval upon request a site-specific performance evaluation test plan for the CMS performance evaluation required in paragraph (e)(3)(i) of this section, according to the procedures specified in paragraph (e). In addition, each quality control program shall include, at a minimum, a written protocol that describes procedures for each of the following operations:

(i) Initial and any subsequent calibration of the CMS;

(ii) Determination and adjustment of the calibration drift of the CMS;

(iii) Preventive maintenance of the CMS, including spare parts inventory;


(iv) Data recording, calculations, and reporting;

(v) Accuracy audit procedures, including sampling and analysis methods; and

(vi) Program of corrective action for a malfunctioning CMS.

(3) The owner or operator shall keep these written procedures on record for the life of the affected source or until the affected source is no longer subject to the provisions of this part, to be made available for inspection, upon request, by the Administrator. If the performance evaluation plan is revised, the owner or operator shall keep previous (i.e., superseded) versions of the performance evaluation plan on record to be made available for inspection, upon request, by the Administrator, for a period of 5 years after each revision to the plan. Where relevant, e.g., program of corrective action for a malfunctioning CMS, these written procedures may be incorporated as part of the affected source's startup, shutdown, and malfunction plan to avoid duplication of planning and recordkeeping efforts.

(e) Performance evaluation of continuous monitoring systems—

(1) General. When required by a relevant standard, and at any other time the Administrator may require under section 114 of the Act, the owner or operator of an affected source being monitored shall conduct a performance evaluation of the CMS. Such performance evaluation shall be conducted according to the applicable specifications and procedures described in this section or in the relevant standard.

(2) Notification of performance evaluation. The owner or operator shall notify the Administrator in writing of the date of the performance evaluation simultaneously with the notification of the performance test date required under §63.7(b) or at least 60 days prior to the date the performance evaluation is scheduled to begin if no performance test is required.

(3)(i) Submission of site-specific performance evaluation test plan. Before conducting a required CMS performance evaluation, the owner or operator of an affected source shall develop and submit a site-specific performance evaluation test plan to the Administrator for approval upon request. The performance evaluation test plan shall include the evaluation program objectives, an evaluation program summary, the performance evaluation schedule, data quality objectives, and both an internal and external QA program. Data quality objectives are the pre-evaluation expectations of precision, accuracy, and completeness of data.

(ii) The internal QA program shall include, at a minimum, the activities planned by routine operators and analysts to provide an assessment of CMS performance. The external QA program shall include, at a minimum, systems audits that include the opportunity for on-site evaluation by the Administrator of instrument calibration, data validation, sample logging, and documentation of quality control data and field maintenance activities.

(iii) The owner or operator of an affected source shall submit the site-specific performance evaluation test plan to the Administrator (if requested) at least 60 days before the performance test or performance evaluation is scheduled to begin, or on a mutually agreed upon date, and review and approval of the performance evaluation test plan by the Administrator will occur with the review and approval of the site-specific test plan (if review of the site-specific test plan is requested).

(iv) The Administrator may request additional relevant information after the submittal of a site-specific performance evaluation test plan.

(v) In the event that the Administrator fails to approve or disapprove the site-specific performance evaluation test plan within the time period specified in §63.7(c)(3), the following conditions shall apply:

(A) If the owner or operator intends to demonstrate compliance using the monitoring method(s) specified in the relevant standard, the owner or operator shall conduct the performance evaluation within the time specified in this subpart using the specified method(s);


(B) If the owner or operator intends to demonstrate compliance by using an alternative to a monitoring method specified in the relevant standard, the owner or operator shall refrain from conducting the performance evaluation until the Administrator approves the use of the alternative method. If the Administrator does not approve the use of the alternative method within 30 days before the performance evaluation is scheduled to begin, the performance evaluation deadlines specified in paragraph (e)(4) of this section may be extended such that the owner or operator shall conduct the performance evaluation within 60 calendar days after the Administrator approves the use of the alternative method. Notwithstanding the requirements in the preceding two sentences, the owner or operator may proceed to conduct the performance evaluation as required in this section (without the Administrator's prior approval of the site-specific performance evaluation test plan) if he/she subsequently chooses to use the specified monitoring method(s) instead of an alternative.

(vi) Neither the submission of a site-specific performance evaluation test plan for approval, nor the Administrator's approval or disapproval of a plan, nor the Administrator's failure to approve or disapprove a plan in a timely manner shall—

(A) Relieve an owner or operator of legal responsibility for compliance with any applicable provisions of this part or with any other applicable Federal, State, or local requirement; or

(B) Prevent the Administrator from implementing or enforcing this part or taking any other action under the Act.

(4) Conduct of performance evaluation and performance evaluation dates. The owner or operator of an affected source shall conduct a performance evaluation of a required CMS during any performance test required under §63.7 in accordance with the applicable performance specification as specified in the relevant standard. Notwithstanding the requirement in the previous sentence, if the owner or operator of an affected source elects to submit COMS data for compliance with a relevant opacity emission standard as provided under §63.6(h)(7), he/she shall conduct a performance evaluation of the COMS as specified in the relevant standard, before the performance test required under §63.7 is conducted in time to submit the results of the performance evaluation as specified in paragraph (e)(5)(ii) of this section. If a performance test is not required, or the requirement for a performance test has been waived under §63.7(h), the owner or operator of an affected source shall conduct the performance evaluation not later than 180 days after the appropriate compliance date for the affected source, as specified in §63.7(a), or as otherwise specified in the relevant standard.

(5) Reporting performance evaluation results.

(i) The owner or operator shall furnish the Administrator a copy of a written report of the results of the performance evaluation simultaneously with the results of the performance test required under §63.7 or within 60 days of completion of the performance evaluation if no test is required, unless otherwise specified in a relevant standard. The Administrator may request that the owner or operator submit the raw data from a performance evaluation in the report of the performance evaluation results.

(ii) The owner or operator of an affected source using a COMS to determine opacity compliance during any performance test required under §63.7 and described in §63.6(d)(6) shall furnish the Administrator two or, upon request, three copies of a written report of the results of the COMS performance evaluation under this paragraph. The copies shall be provided at least 15 calendar days before the performance test required under §63.7 is conducted.

(f) Use of an alternative monitoring method—

(1) General. Until permission to use an alternative monitoring procedure (minor, intermediate, or major changes; see definition in §63.90(a)) has been granted by the Administrator under this paragraph (f)(1), the owner or operator of an affected source remains subject to the requirements of this section and the relevant standard.


(2) After receipt and consideration of written application, the Administrator may approve alternatives to any monitoring methods or procedures of this part including, but not limited to, the following:

(i) Alternative monitoring requirements when installation of a CMS specified by a relevant standard would not provide accurate measurements due to liquid water or other interferences caused by substances within the effluent gases;

(ii) Alternative monitoring requirements when the affected source is infrequently operated;

(iii) Alternative monitoring requirements to accommodate CEMS that require additional measurements to correct for stack moisture conditions;

(iv) Alternative locations for installing CMS when the owner or operator can demonstrate that installation at alternate locations will enable accurate and representative measurements;

(v) Alternate methods for converting pollutant concentration measurements to units of the relevant standard;

(vi) Alternate procedures for performing daily checks of zero (low-level) and high-level drift that do not involve use of high-level gases or test cells;

(vii) Alternatives to the American Society for Testing and Materials (ASTM) test methods or sampling procedures specified by any relevant standard;

(viii) Alternative CMS that do not meet the design or performance requirements in this part, but adequately demonstrate a definite and consistent relationship between their measurements and the measurements of opacity by a system complying with the requirements as specified in the relevant standard. The Administrator may require that such demonstration be performed for each affected source; or

(ix) Alternative monitoring requirements when the effluent from a single affected source or the combined effluent from two or more affected sources is released to the atmosphere through more than one point.

(3) If the Administrator finds reasonable grounds to dispute the results obtained by an alternative monitoring method, requirement, or procedure, the Administrator may require the use of a method, requirement, or procedure specified in this section or in the relevant standard. If the results of the specified and alternative method, requirement, or procedure do not agree, the results obtained by the specified method, requirement, or procedure shall prevail.

(4)(i) Request to use alternative monitoring procedure. An owner or operator who wishes to use an alternative monitoring procedure must submit an application to the Administrator as described in paragraph (f)(4)(ii) of this section. The application may be submitted at any time provided that the monitoring procedure is not the performance test method used to demonstrate compliance with a relevant standard or other requirement. If the alternative monitoring procedure will serve as the performance test method that is to be used to demonstrate compliance with a relevant standard, the application must be submitted at least 60 days before the performance evaluation is scheduled to begin and must meet the requirements for an alternative test method under §63.7(f).

(ii) The application must contain a description of the proposed alternative monitoring system which addresses the four elements contained in the definition of monitoring in §63.2 and a performance evaluation test plan, if required, as specified in paragraph (e)(3) of this section. In addition, the application must include information justifying the owner or operator's request for an alternative monitoring method, such as the technical or economic infeasibility, or the impracticality, of the affected source using the required method.

(iii) The owner or operator may submit the information required in this paragraph well in advance of the submittal dates specified in paragraph (f)(4)(i) above to ensure a timely review by the Administrator in order to meet the compliance demonstration date specified in this section or the relevant standard.

(iv) Application for minor changes to monitoring procedures, as specified in paragraph (b)(1) of this section, may be made in the site-specific performance evaluation plan.


(5) Approval of request to use alternative monitoring procedure.

(i) The Administrator will notify the owner or operator of approval or intention to deny approval of the request to use an alternative monitoring method within 30 calendar days after receipt of the original request and within 30 calendar days after receipt of any supplementary information that is submitted. If a request for a minor change is made in conjunction with site-specific performance evaluation plan, then approval of the plan will constitute approval of the minor change. Before disapproving any request to use an alternative monitoring method, the Administrator will notify the applicant of the Administrator's intention to disapprove the request together with—

(A) Notice of the information and findings on which the intended disapproval is based; and

(B) Notice of opportunity for the owner or operator to present additional information to the Administrator before final action on the request. At the time the Administrator notifies the applicant of his or her intention to disapprove the request, the Administrator will specify how much time the owner or operator will have after being notified of the intended disapproval to submit the additional information.

(ii) The Administrator may establish general procedures and criteria in a relevant standard to accomplish the requirements of paragraph (f)(5)(i) of this section.

(iii) If the Administrator approves the use of an alternative monitoring method for an affected source under paragraph (f)(5)(i) of this section, the owner or operator of such source shall continue to use the alternative monitoring method until he or she receives approval from the Administrator to use another monitoring method as allowed by §63.8(f).

(6) Alternative to the relative accuracy test. An alternative to the relative accuracy test for CEMS specified in a relevant standard may be requested as follows:

(i) Criteria for approval of alternative procedures. An alternative to the test method for determining relative accuracy is available for affected sources with emission rates demonstrated to be less than 50 percent of the relevant standard. The owner or operator of an affected source may petition the Administrator under paragraph (f)(6)(ii) of this section to substitute the relative accuracy test in section 7 of Performance Specification 2 with the procedures in section 10 if the results of a performance test conducted according to the requirements in §63.7, or other tests performed following the criteria in §63.7, demonstrate that the emission rate of the pollutant of interest in the units of the relevant standard is less than 50 percent of the relevant standard. For affected sources subject to emission limitations expressed as control efficiency levels, the owner or operator may petition the Administrator to substitute the relative accuracy test with the procedures in section 10 of Performance Specification 2 if the control device exhaust emission rate is less than 50 percent of the level needed to meet the control efficiency requirement. The alternative procedures do not apply if the CEMS is used continuously to determine compliance with the relevant standard.

(ii) Petition to use alternative to relative accuracy test. The petition to use an alternative to the relative accuracy test shall include a detailed description of the procedures to be applied, the location and the procedure for conducting the alternative, the concentration or response levels of the alternative relative accuracy materials, and the other equipment checks included in the alternative procedure(s). The Administrator will review the petition for completeness and applicability. The Administrator's determination to approve an alternative will depend on the intended use of the CEMS data and may require specifications more stringent than in Performance Specification 2.

(iii) Rescission of approval to use alternative to relative accuracy test. The Administrator will review the permission to use an alternative to the CEMS relative accuracy test and may rescind such permission if the CEMS data from a successful completion of the alternative relative accuracy procedure indicate that the affected


source's emissions are approaching the level of the relevant standard. The criterion for reviewing the permission is that the collection of CEMS data shows that emissions have exceeded 70 percent of the relevant standard for any averaging period, as specified in the relevant standard. For affected sources subject to emission limitations expressed as control efficiency levels, the criterion for reviewing the permission is that the collection of CEMS data shows that exhaust emissions have exceeded 70 percent of the level needed to meet the control efficiency requirement for any averaging period, as specified in the relevant standard. The owner or operator of the affected source shall maintain records and determine the level of emissions relative to the criterion for permission to use an alternative for relative accuracy testing. If this criterion is exceeded, the owner or operator shall notify the Administrator within 10 days of such occurrence and include a description of the nature and cause of the increased emissions. The Administrator will review the notification and may rescind permission to use an alternative and require the owner or operator to conduct a relative accuracy test of the CEMS as specified in section 7 of Performance Specification 2. The Administrator will review the notification and may rescind permission to use an alternative and require the owner or operator to conduct a relative accuracy test of the CEMS as specified in section 8.4 of Performance Specification 2.

(g) Reduction of monitoring data.

(1) The owner or operator of each CMS must reduce the monitoring data as specified in paragraphs (g)(1) through (5) of this section.

(2) The owner or operator of each COMS shall reduce all data to 6-minute averages calculated from 36 or more data points equally spaced over each 6-minute period. Data from CEMS for measurement other than opacity, unless otherwise specified in the relevant standard, shall be reduced to 1-hour averages computed from four or more data points equally spaced over each 1-hour period, except during periods when calibration, quality assurance, or maintenance activities pursuant to provisions of this part are being performed. During these periods, a valid hourly average shall consist of at least two data points with each representing a 15-minute period. Alternatively, an arithmetic or integrated 1-hour average of CEMS data may be used. Time periods for averaging are defined in §63.2.

(3) The data may be recorded in reduced or nonreduced form (e.g., ppm pollutant and percent O2 or ng/J of pollutant).

(4) All emission data shall be converted into units of the relevant standard for reporting purposes using the conversion procedures specified in that standard. After conversion into units of the relevant standard, the data may be rounded to the same number of significant digits as used in that standard to specify the emission limit (e.g., rounded to the nearest 1 percent opacity).

(5) Monitoring data recorded during periods of unavoidable CMS breakdowns, out-of-control periods, repairs, maintenance periods, calibration checks, and zero (low-level) and high-level adjustments must not be included in any data average computed under this part. For the owner or operator complying with the requirements of §63.10(b)(2)(vii)(A) or (B), data averages must include any data recorded during periods of monitor breakdown or malfunction.

§63.9 Notification requirements.

(a) Applicability and general information.


(2) For affected sources that have been granted an extension of compliance under subpart D of this part, the requirements of this section do not apply to those sources while they are operating under such compliance extensions.

(3) If any State requires a notice that contains all the information required in a notification listed in this section, the owner or operator may send the Administrator a copy of the notice sent to the State to satisfy the requirements of this section for that notification.


(4)(i) Before a State has been delegated the authority to implement and enforce notification requirements established under this part, the owner or operator of an affected source in such State subject to such requirements shall submit notifications to the appropriate Regional Office of the EPA (to the attention of the Director of the Division indicated in the list of the EPA Regional Offices in §63.13).

(ii) After a State has been delegated the authority to implement and enforce notification requirements established under this part, the owner or operator of an affected source in such State subject to such requirements shall submit notifications to the delegated State authority (which may be the same as the permitting authority). In addition, if the delegated (permitting) authority is the State, the owner or operator shall send a copy of each notification submitted to the State to the appropriate Regional Office of the EPA, as specified in paragraph (a)(4)(i) of this section. The Regional Office may waive this requirement for any notifications at its discretion.

(b) Initial notifications.

(1)(i) The requirements of this paragraph apply to the owner or operator of an affected source when such source becomes subject to a relevant standard.

(ii) If an area source that otherwise would be subject to an emission standard or other requirement established under this part if it were a major source subsequently increases its emissions of hazardous air pollutants (or its potential to emit hazardous air pollutants) such that the source is a major source that is subject to the emission standard or other requirement, such source shall be subject to the notification requirements of this section.

(iii) Affected sources that are required under this paragraph to submit an initial notification may use the application for approval of construction or reconstruction under §63.5(d) of this subpart, if relevant, to fulfill the initial notification requirements of this paragraph.

(2) The owner or operator of an affected source that has an initial startup before the effective date of a relevant standard under this part shall notify the Administrator in writing that the source is subject to the relevant standard. The notification, which shall be submitted not later than 120 calendar days after the effective date of the relevant standard (or within 120 calendar days after the source becomes subject to the relevant standard), shall provide the following information:

(i) The name and address of the owner or operator;

(ii) The address (i.e., physical location) of the affected source;

(iii) An identification of the relevant standard, or other requirement, that is the basis of the notification and the source's compliance date;

(iv) A brief description of the nature, size, design, and method of operation of the source and an identification of the types of emission points within the affected source subject to the relevant standard and types of hazardous air pollutants emitted; and

(v) A statement of whether the affected source is a major source or an area source.

(3) [Reserved]

(4) The owner or operator of a new or reconstructed major affected source for which an application for approval of construction or reconstruction is required under §63.5(d) must provide the following information in writing to the Administrator:

(i) A notification of intention to construct a new major-emitting affected source, reconstruct a major-emitting affected source, or reconstruct a major source such that the source becomes a major-emitting affected source with the application for approval of construction or reconstruction as specified in §63.5(d)(1)(i); and


(ii)-(iv) [Reserved]

(v) A notification of the actual date of startup of the source, delivered or postmarked within 15 calendar days after that date.

(5) The owner or operator of a new or reconstructed affected source for which an application for approval of construction or reconstruction is not required under §63.5(d) must provide the following information in writing to the Administrator:

(i) A notification of intention to construct a new affected source, reconstruct an affected source, or reconstruct a source such that the source becomes an affected source, and

(ii) A notification of the actual date of startup of the source, delivered or postmarked within 15 calendar days after that date.

(iii) Unless the owner or operator has requested and received prior permission from the Administrator to submit less than the information in §63.5(d), the notification must include the information required on the application for approval of construction or reconstruction as specified in §63.5(d)(1)(i).

(c) Request for extension of compliance. If the owner or operator of an affected source cannot comply with a relevant standard by the applicable compliance date for that source, or if the owner or operator has installed BACT or technology to meet LAER consistent with §63.6(i)(5) of this subpart, he/she may submit to the Administrator (or the State with an approved permit program) a request for an extension of compliance as specified in §63.6(i)(4) through §63.6(i)(6).

(d) Notification that source is subject to special compliance requirements. An owner or operator of a new source that is subject to special compliance requirements as specified in §63.6(b)(3) and §63.6(b)(4) shall notify the Administrator of his/her compliance obligations not later than the notification dates established in paragraph (b) of this section for new sources that are not subject to the special provisions.

(e) Notification of performance test. The owner or operator of an affected source shall notify the Administrator in writing of his or her intention to conduct a performance test at least 60 calendar days before the performance test is scheduled to begin to allow the Administrator to review and approve the site-specific test plan required under §63.7(c), if requested by the Administrator, and to have an observer present during the test.

(f) Notification of opacity and visible emission observations. The owner or operator of an affected source shall notify the Administrator in writing of the anticipated date for conducting the opacity or visible emission observations specified in §63.6(h)(5), if such observations are required for the source by a relevant standard. The notification shall be submitted with the notification of the performance test date, as specified in paragraph (e) of this section, or if no performance test is required or visibility or other conditions prevent the opacity or visible emission observations from being conducted concurrently with the initial performance test required under §63.7, the owner or operator shall deliver or postmark the notification not less than 30 days before the opacity or visible emission observations are scheduled to take place.

(g) Additional notification requirements for sources with continuous monitoring systems. The owner or operator of an affected source required to use a CMS by a relevant standard shall furnish the Administrator written notification as follows:

(1) A notification of the date the CMS performance evaluation under §63.8(e) is scheduled to begin, submitted simultaneously with the notification of the performance test date required under §63.7(b). If no performance test is required, or if the requirement to conduct a performance test has been waived for an affected source under §63.7(h), the owner or operator shall notify the Administrator in writing of the date of the performance evaluation at least 60 calendar days before the evaluation is scheduled to begin;

(2) A notification that COMS data results will be used to determine compliance with the applicable opacity emission standard during a performance test required by §63.7 in lieu of Method 9 or other opacity emissions test method data, as allowed by §63.6(h)(7)(ii), if compliance with an opacity emission standard is required for the source by a relevant


standard. The notification shall be submitted at least 60 calendar days before the performance test is scheduled to begin; and

(3) A notification that the criterion necessary to continue use of an alternative to relative accuracy testing, as provided by §63.8(f)(6), has been exceeded. The notification shall be delivered or postmarked not later than 10 days after the occurrence of such exceedance, and it shall include a description of the nature and cause of the increased emissions.

(h) Notification of compliance status. (1) The requirements of paragraphs (h)(2) through (h)(4) of this section apply when an affected source becomes subject to a relevant standard.

(2)(i) Before a title V permit has been issued to the owner or operator of an affected source, and each time a notification of compliance status is required under this part, the owner or operator of such source shall submit to the Administrator a notification of compliance status, signed by the responsible official who shall certify its accuracy, attesting to whether the source has complied with the relevant standard. The notification shall list—

(A) The methods that were used to determine compliance;

(B) The results of any performance tests, opacity or visible emission observations, continuous monitoring system (CMS) performance evaluations, and/or other monitoring procedures or methods that were conducted;

(C) The methods that will be used for determining continuing compliance, including a description of monitoring and reporting requirements and test methods;

(D) The type and quantity of hazardous air pollutants emitted by the source (or surrogate pollutants if specified in the relevant standard), reported in units and averaging times and in accordance with the test methods specified in the relevant standard;

(E) If the relevant standard applies to both major and area sources, an analysis demonstrating whether the affected source is a major source (using the emissions data generated for this notification);

(F) A description of the air pollution control equipment (or method) for each emission point, including each control device (or method) for each hazardous air pollutant and the control efficiency (percent) for each control device (or method); and

(G) A statement by the owner or operator of the affected existing, new, or reconstructed source as to whether the source has complied with the relevant standard or other requirements.

(ii) The notification must be sent before the close of business on the 60th day following the completion of the relevant compliance demonstration activity specified in the relevant standard (unless a different reporting period is specified in the standard, in which case the letter must be sent before the close of business on the day the report of the relevant testing or monitoring results is required to be delivered or postmarked). For example, the notification shall be sent before close of business on the 60th (or other required) day following completion of the initial performance test and again before the close of business on the 60th (or other required) day following the completion of any subsequent required performance test. If no performance test is required but opacity or visible emission observations are required to demonstrate compliance with an opacity or visible emission standard under this part, the notification of compliance status shall be sent before close of business on the 30th day following the completion of opacity or visible emission observations. Notifications may be combined as long as the due date requirement for each notification is met.

(3) After a title V permit has been issued to the owner or operator of an affected source, the owner or operator of such source shall comply with all requirements for compliance status reports contained in the source's title V permit, including reports required under this part. After a title V permit has been issued to the owner or operator of an affected source, and each time a notification of compliance status is required under this part, the owner or operator of such source shall


submit the notification of compliance status to the appropriate permitting authority following completion of the relevant compliance demonstration activity specified in the relevant standard.

(4) [Reserved]

(5) If an owner or operator of an affected source submits estimates or preliminary information in the application for approval of construction or reconstruction required in §63.5(d) in place of the actual emissions data or control efficiencies required in paragraphs (d)(1)(ii)(H) and (d)(2) of §63.5, the owner or operator shall submit the actual emissions data and other correct information as soon as available but no later than with the initial notification of compliance status required in this section.

(6) Advice on a notification of compliance status may be obtained from the Administrator.

(i) Adjustment to time periods or postmark deadlines for submittal and review of required communications.

(1)(i) Until an adjustment of a time period or postmark deadline has been approved by the Administrator under paragraphs (i)(2) and (i)(3) of this section, the owner or operator of an affected source remains strictly subject to the requirements of this part.

(ii) An owner or operator shall request the adjustment provided for in paragraphs (i)(2) and (i)(3) of this section each time he or she wishes to change an applicable time period or postmark deadline specified in this part.

(2) Notwithstanding time periods or postmark deadlines specified in this part for the submittal of information to the Administrator by an owner or operator, or the review of such information by the Administrator, such time periods or deadlines may be changed by mutual agreement between the owner or operator and the Administrator. An owner or operator 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 owner or operator 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, an owner or operator'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 owner or operator 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 owner or operator of any significant delay and inform the owner or operator of the amended schedule.

(j) Change in information already provided. Any change in the information already provided under this section shall be provided to the Administrator in writing within 15 calendar days after the change.

§63.10 Recordkeeping and reporting requirements.

(a) Applicability and general information. (1) The applicability of this section is set out in §63.1(a)(4).

(2) For affected sources that have been granted an extension of compliance under subpart D of this part, the requirements of this section do not apply to those sources while they are operating under such compliance extensions.

(3) If any State requires a report that contains all the information required in a report listed in this section, an owner or operator may send the Administrator a copy of the report sent to the State to satisfy the requirements of this section for that report.

(4)(i) Before a State has been delegated the authority to implement and enforce recordkeeping and reporting requirements established under this part, the owner or operator of an affected source in such State subject to such


requirements shall submit reports to the appropriate Regional Office of the EPA (to the attention of the Director of the Division indicated in the list of the EPA Regional Offices in §63.13).

(ii) After a State has been delegated the authority to implement and enforce recordkeeping and reporting requirements established under this part, the owner or operator of an affected source in such State subject to such requirements shall submit reports to the delegated State authority (which may be the same as the permitting authority). In addition, if the delegated (permitting) authority is the State, the owner or operator shall send a copy of each report submitted to the State to the appropriate Regional Office of the EPA, as specified in paragraph (a)(4)(i) of this section. The Regional Office may waive this requirement for any reports at its discretion.

(5) If an owner or operator of an affected source in a State with delegated authority is required to submit periodic reports under this part to the State, and if the State has an established timeline for the submission of periodic reports that is consistent with the reporting frequency(ies) specified for such source under this part, the owner or operator may change the dates by which periodic reports under this part shall be submitted (without changing the frequency of reporting) to be consistent with the State's schedule by mutual agreement between the owner or operator and the State. For each relevant standard established pursuant to section 112 of the Act, the allowance in the previous sentence applies in each State beginning 1 year after the affected source's compliance date for that standard. Procedures governing the implementation of this provision are specified in §63.9(i).

(6) If an owner or operator supervises one or more stationary sources affected by more than one standard established pursuant to section 112 of the Act, he/she may arrange by mutual agreement between the owner or operator and the Administrator (or the State permitting authority) a common schedule on which periodic reports required for each source shall be submitted throughout the year. The allowance in the previous sentence applies in each State beginning 1 year after the latest compliance date for any relevant standard established pursuant to section 112 of the Act for any such affected source(s). Procedures governing the implementation of this provision are specified in §63.9(i).

(7) If an owner or operator supervises one or more stationary sources affected by standards established pursuant to section 112 of the Act (as amended November 15, 1990) and standards set under part 60, part 61, or both such parts of this chapter, he/she may arrange by mutual agreement between the owner or operator and the Administrator (or the State permitting authority) a common schedule on which periodic reports required by each relevant (i.e., applicable) standard shall be submitted throughout the year. The allowance in the previous sentence applies in each State beginning 1 year after the stationary source is required to be in compliance with the relevant section 112 standard, or 1 year after the stationary source is required to be in compliance with the applicable part 60 or part 61 standard, whichever is latest. Procedures governing the implementation of this provision are specified in §63.9(i).

(b) General recordkeeping requirements.

(1) The owner or operator of an affected source subject to the provisions of this part shall maintain files of all information (including all reports and notifications) required by this part recorded in a form suitable and readily available for expeditious inspection and review. The files shall be retained for at least 5 years following the date of each occurrence, measurement, maintenance, corrective action, report, or record. At a minimum, the most recent 2 years of data shall be retained on site. The remaining 3 years of data may be retained off site. Such files may be maintained on microfilm, on a computer, on computer floppy disks, on magnetic tape disks, or on microfiche.

(2) The owner or operator of an affected source subject to the provisions of this part shall maintain relevant records for such source of—

(i) The occurrence and duration of each startup or shutdown when the startup or shutdown causes the source to exceed any applicable emission limitation in the relevant emission standards;

(ii) The occurrence and duration of each malfunction of operation (i.e., process equipment) or the required air pollution control and monitoring equipment;


(iii) All required maintenance performed on the air pollution control and monitoring equipment;

(iv)(A) Actions taken during periods of startup or shutdown when the source exceeded applicable emission limitations in a relevant standard and when the actions taken are different from the procedures specified in the affected source's startup, shutdown, and malfunction plan (see §63.6(e)(3)); or

(B) Actions taken during periods of malfunction (including corrective actions to restore malfunctioning process and air pollution control and monitoring equipment to its normal or usual manner of operation) when the actions taken are different from the procedures specified in the affected source's startup, shutdown, and malfunction plan (see §63.6(e)(3));

(v) All information necessary, including actions taken, to demonstrate conformance with the affected source's startup, shutdown, and malfunction plan (see §63.6(e)(3)) when all actions taken during periods of startup or shutdown (and the startup or shutdown causes the source to exceed any applicable emission limitation in the relevant emission standards), and malfunction (including corrective actions to restore malfunctioning process and air pollution control and monitoring equipment to its normal or usual manner of operation) are consistent with the procedures specified in such plan. (The information needed to demonstrate conformance with the startup, shutdown, and malfunction plan may be recorded using a “checklist,” or some other effective form of recordkeeping, in order to minimize the recordkeeping burden for conforming events);

(vi) Each period during which a CMS is malfunctioning or inoperative (including out-of-control periods);

(vii) All required measurements needed to demonstrate compliance with a relevant standard (including, but not limited to, 15-minute averages of CMS data, raw performance testing measurements, and raw performance evaluation measurements, that support data that the source is required to report);

(A) This paragraph applies to owners or operators required to install a continuous emissions monitoring system (CEMS) where the CEMS installed is automated, and where the calculated data averages do not exclude periods of CEMS breakdown or malfunction. An automated CEMS records and reduces the measured data to the form of the pollutant emission standard through the use of a computerized data acquisition system. In lieu of maintaining a file of all CEMS subhourly measurements as required under paragraph (b)(2)(vii) of this section, the owner or operator shall retain the most recent consecutive three averaging periods of subhourly measurements and a file that contains a hard copy of the data acquisition system algorithm used to reduce the measured data into the reportable form of the standard.

(B) This paragraph applies to owners or operators required to install a CEMS where the measured data is manually reduced to obtain the reportable form of the standard, and where the calculated data averages do not exclude periods of CEMS breakdown or malfunction. In lieu of maintaining a file of all CEMS subhourly measurements as required under paragraph (b)(2)(vii) of this section, the owner or operator shall retain all subhourly measurements for the most recent reporting period. The subhourly measurements shall be retained for 120 days from the date of the most recent summary or excess emission report submitted to the Administrator.

(C) The Administrator or delegated authority, upon notification to the source, may require the owner or operator to maintain all measurements as required by paragraph (b)(2)(vii), if the administrator or the delegated authority determines these records are required to more accurately assess the compliance status of the affected source.

(viii) All results of performance tests, CMS performance evaluations, and opacity and visible emission observations;

(ix) All measurements as may be necessary to determine the conditions of performance tests and performance evaluations;


(x) All CMS calibration checks;

(xi) All adjustments and maintenance performed on CMS;

(xii) Any information demonstrating whether a source is meeting the requirements for a waiver of recordkeeping or reporting requirements under this part, if the source has been granted a waiver under paragraph (f) of this section;

(xiii) All emission levels relative to the criterion for obtaining permission to use an alternative to the relative accuracy test, if the source has been granted such permission under §63.8(f)(6); and

(xiv) All documentation supporting initial notifications and notifications of compliance status under §63.9.

(3) Recordkeeping requirement for applicability determinations. If an owner or operator determines that his or her stationary source that emits (or has the potential to emit, without considering controls) one or more hazardous air pollutants regulated by any standard established pursuant to section 112(d) or (f), and that stationary source is in the source category regulated by the relevant standard, but that source is not subject to the relevant standard (or other requirement established under this part) because of limitations on the source's potential to emit or an exclusion, the owner or operator must keep a record of the applicability determination on site at the source for a period of 5 years after the determination, or until the source changes its operations to become an affected source, whichever comes first. The record of the applicability determination must be signed by the person making the determination and include an analysis (or other information) that demonstrates why the owner or operator believes the source is unaffected (e.g., because the source is an area source). The analysis (or other information) must be sufficiently detailed to allow the Administrator to make a finding about the source's applicability status with regard to the relevant standard or other requirement. If relevant, the analysis must be performed in accordance with requirements established in relevant subparts of this part for this purpose for particular categories of stationary sources. If relevant, the analysis should be performed in accordance with EPA guidance materials published to assist sources in making applicability determinations under section 112, if any. The requirements to determine applicability of a standard under §63.1(b)(3) and to record the results of that determination under paragraph (b)(3) of this section shall not by themselves create an obligation for the owner or operator to obtain a title V permit.

(c) Additional recordkeeping requirements for sources with continuous monitoring systems. In addition to complying with the requirements specified in paragraphs (b)(1) and (b)(2) of this section, the owner or operator of an affected source required to install a CMS by a relevant standard shall maintain records for such source of—

(1) All required CMS measurements (including monitoring data recorded during unavoidable CMS breakdowns and out-of-control periods);

(2)-(4) [Reserved]

(5) The date and time identifying each period during which the CMS was inoperative except for zero (low-level) and high-level checks;

(6) The date and time identifying each period during which the CMS was out of control, as defined in §63.8(c)(7);

(7) The specific identification (i.e., the date and time of commencement and completion) of each period of excess emissions and parameter monitoring exceedances, as defined in the relevant standard(s), that occurs during startups, shutdowns, and malfunctions of the affected source;

(8) The specific identification (i.e., the date and time of commencement and completion) of each time period of excess emissions and parameter monitoring exceedances, as defined in the relevant standard(s), that occurs during periods other than startups, shutdowns, and malfunctions of the affected source;

(9) [Reserved]

(10) The nature and cause of any malfunction (if known);


(11) The corrective action taken or preventive measures adopted;

(12) The nature of the repairs or adjustments to the CMS that was inoperative or out of control;

(13) The total process operating time during the reporting period; and

(14) All procedures that are part of a quality control program developed and implemented for CMS under §63.8(d).

(15) In order to satisfy the requirements of paragraphs (c)(10) through (c)(12) of this section and to avoid duplicative recordkeeping efforts, the owner or operator may use the affected source's startup, shutdown, and malfunction plan or records kept to satisfy the recordkeeping requirements of the startup, shutdown, and malfunction plan specified in §63.6(e), provided that such plan and records adequately address the requirements of paragraphs (c)(10) through (c)(12).

(d) General reporting requirements.

(1) Notwithstanding the requirements in this paragraph or paragraph (e) of this section, and except as provided in §63.16, the owner or operator of an affected source subject to reporting requirements under this part shall submit reports to the Administrator in accordance with the reporting requirements in the relevant standard(s).

(2) Reporting results of performance tests. Before a title V permit has been issued to the owner or operator of an affected source, the owner or operator shall report the results of any performance test under §63.7 to the Administrator. After a title V permit has been issued to the owner or operator of an affected source, the owner or operator shall report the results of a required performance test to the appropriate permitting authority. The owner or operator of an affected source shall report the results of the performance test to the Administrator (or the State with an approved permit program) before the close of business on the 60th day following the completion of the performance test, unless specified otherwise in a relevant standard or as approved otherwise in writing by the Administrator. The results of the performance test shall be submitted as part of the notification of compliance status required under §63.9(h).

(3) Reporting results of opacity or visible emission observations. The owner or operator of an affected source required to conduct opacity or visible emission observations by a relevant standard shall report the opacity or visible emission results (produced using Test Method 9 or Test Method 22, or an alternative to these test methods) along with the results of the performance test required under §63.7. If no performance test is required, or if visibility or other conditions prevent the opacity or visible emission observations from being conducted concurrently with the performance test required under §63.7, the owner or operator shall report the opacity or visible emission results before the close of business on the 30th day following the completion of the opacity or visible emission observations.

(4) Progress reports. The owner or operator of an affected source who is required to submit progress reports as a condition of receiving an extension of compliance under §63.6(i) shall submit such reports to the Administrator (or the State with an approved permit program) by the dates specified in the written extension of compliance.

(5)(i) Periodic startup, shutdown, and malfunction reports. If actions taken by an owner or operator during a startup or shutdown (and the startup or shutdown causes the source to exceed any applicable emission limitation in the relevant emission standards), or malfunction of an affected source (including actions taken to correct a malfunction) are consistent with the procedures specified in the source's startup, shutdown, and malfunction plan (see §63.6(e)(3)), the owner or operator shall state such information in a startup, shutdown, and malfunction report. Actions taken to minimize emissions during such startups, shutdowns, and malfunctions shall be summarized in the report and may be done in checklist form; if actions taken are the same for each event, only one checklist is necessary. Such a report shall also include the number, duration, and a brief description for each type of malfunction which occurred during the reporting period and which caused or may have caused any applicable emission limitation to be exceeded. Reports shall only be required if a startup or shutdown caused the source to exceed any applicable emission limitation in the relevant emission standards, or if a malfunction occurred during the reporting period. The startup, shutdown, and malfunction report shall consist of a letter, containing the name, title, and signature of the owner or operator or other responsible official who is certifying its accuracy, that shall be submitted to the Administrator semiannually (or on a more frequent basis if specified otherwise in a relevant standard or as established otherwise by the permitting authority in the source's


title V permit). The startup, shutdown, and malfunction report shall be delivered or postmarked by the 30th day following the end of each calendar half (or other calendar reporting period, as appropriate). If the owner or operator is required to submit excess emissions and continuous monitoring system performance (or other periodic) reports under this part, the startup, shutdown, and malfunction reports required under this paragraph may be submitted simultaneously with the excess emissions and continuous monitoring system performance (or other) reports. If startup, shutdown, and malfunction reports are submitted with excess emissions and continuous monitoring system performance (or other periodic) reports, and the owner or operator receives approval to reduce the frequency of reporting for the latter under paragraph (e) of this section, the frequency of reporting for the startup, shutdown, and malfunction reports also may be reduced if the Administrator does not object to the intended change. The procedures to implement the allowance in the preceding sentence shall be the same as the procedures specified in paragraph (e)(3) of this section.

(ii) Immediate startup, shutdown, and malfunction reports. Notwithstanding the allowance to reduce the frequency of reporting for periodic startup, shutdown, and malfunction reports under paragraph (d)(5)(i) of this section, any time an action taken by an owner or operator during a startup or shutdown that caused the source to exceed any applicable emission limitation in the relevant emission standards, or malfunction (including actions taken to correct a malfunction) is not consistent with the procedures specified in the affected source's startup, shutdown, and malfunction plan, the owner or operator shall report the actions taken for that event within 2 working days after commencing actions inconsistent with the plan followed by a letter within 7 working days after the end of the event. The immediate report required under this paragraph (d)(5)(ii) shall consist of a telephone call (or facsimile (FAX) transmission) to the Administrator within 2 working days after commencing actions inconsistent with the plan, and it shall be followed by a letter, delivered or postmarked within 7 working days after the end of the event, that contains the name, title, and signature of the owner or operator or other responsible official who is certifying its accuracy, explaining the circumstances of the event, the reasons for not following the startup, shutdown, and malfunction plan, describing all excess emissions and/or parameter monitoring exceedances which are believed to have occurred (or could have occurred in the case of malfunctions), and actions taken to minimize emissions in conformance with §63.6(e)(1)(i). Notwithstanding the requirements of the previous sentence, after the effective date of an approved permit program in the State in which an affected source is located, the owner or operator may make alternative reporting arrangements, in advance, with the permitting authority in that State. Procedures governing the arrangement of alternative reporting requirements under this paragraph (d)(5)(ii) are specified in §63.9(i).

(e) Additional reporting requirements for sources with continuous monitoring systems—

(1) General. When more than one CEMS is used to measure the emissions from one affected source (e.g., multiple breechings, multiple outlets), the owner or operator shall report the results as required for each CEMS.

(2) Reporting results of continuous monitoring system performance evaluations.

(i) The owner or operator of an affected source required to install a CMS by a relevant standard shall furnish the Administrator a copy of a written report of the results of the CMS performance evaluation, as required under §63.8(e), simultaneously with the results of the performance test required under §63.7, unless otherwise specified in the relevant standard.

(ii) The owner or operator of an affected source using a COMS to determine opacity compliance during any performance test required under §63.7 and described in §63.6(d)(6) shall furnish the Administrator two or, upon request, three copies of a written report of the results of the COMS performance evaluation conducted under §63.8(e). The copies shall be furnished at least 15 calendar days before the performance test required under §63.7 is conducted.

(3) Excess emissions and continuous monitoring system performance report and summary report.


(i) Excess emissions and parameter monitoring exceedances are defined in relevant standards. The owner or operator of an affected source required to install a CMS by a relevant standard shall submit an excess emissions and continuous monitoring system performance report and/or a summary report to the Administrator semiannually, except when—

(A) More frequent reporting is specifically required by a relevant standard;

(B) The Administrator determines on a case-by-case basis that more frequent reporting is necessary to accurately assess the compliance status of the source; or

(C) [Reserved]

(D) The affected source is complying with the Performance Track Provisions of §63.16, which allows less frequent reporting.

(ii) Request to reduce frequency of excess emissions and continuous monitoring system performance reports. Notwithstanding the frequency of reporting requirements specified in paragraph (e)(3)(i) of this section, an owner or operator who is required by a relevant standard to submit excess emissions and continuous monitoring system performance (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:

(A) For 1 full year (e.g., 4 quarterly or 12 monthly reporting periods) the affected source's excess emissions and continuous monitoring system performance reports continually demonstrate that the source is in compliance with the relevant standard;

(B) The owner or operator continues to comply with all recordkeeping and monitoring requirements specified in this subpart and the relevant standard; and

(C) The Administrator does not object to a reduced frequency of reporting for the affected source, as provided in paragraph (e)(3)(iii) of this section.

(iii) The frequency of reporting of excess emissions and continuous monitoring system performance (and summary) reports required to comply with a relevant standard may be reduced only after the owner or operator 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 5-year recordkeeping period prior to the intended change, including performance test results, monitoring data, and evaluations of an owner or operator'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 owner or operator's request to reduce the frequency of reporting, the Administrator will notify the owner or operator in writing within 45 days after receiving notice of the owner or operator's intention. The notification from the Administrator to the owner or operator 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.

(iv) As soon as CMS data indicate that the source is not in compliance with any emission limitation or operating parameter specified in the relevant standard, the frequency of reporting shall revert to the frequency specified in the relevant standard, and the owner or operator shall submit an excess emissions and continuous monitoring system performance (and summary) report for the noncomplying emission points at the next appropriate reporting period following the noncomplying event. After demonstrating ongoing compliance with the relevant standard for another full year, the owner or operator may again request approval from the Administrator to reduce the frequency of reporting for that standard, as provided for in paragraphs (e)(3)(ii) and (e)(3)(iii) of this section.


(v) Content and submittal dates for excess emissions and monitoring system performance reports. All excess emissions and monitoring system performance reports and all summary reports, if required, shall be delivered or postmarked by the 30th day following the end of each calendar half or quarter, as appropriate. Written reports of excess emissions or exceedances of process or control system parameters shall include all the information required in paragraphs (c)(5) through (c)(13) of this section, in §§63.8(c)(7) and 63.8(c)(8), and in the relevant standard, and they shall contain the name, title, and signature of the responsible official who is certifying the accuracy of the report. When no excess emissions or exceedances of a parameter have occurred, or a CMS has not been inoperative, out of control, repaired, or adjusted, such information shall be stated in the report.

(vi) Summary report. As required under paragraphs (e)(3)(vii) and (e)(3)(viii) of this section, one summary report shall be submitted for the hazardous air pollutants monitored at each affected source (unless the relevant standard specifies that more than one summary report is required, e.g., one summary report for each hazardous air pollutant monitored). The summary report shall be entitled “Summary Report—Gaseous and Opacity Excess Emission and Continuous Monitoring System Performance” and shall contain the following information:

(A) The company name and address of the affected source;

(B) An identification of each hazardous air pollutant monitored at the affected source;

(C) The beginning and ending dates of the reporting period;

(D) A brief description of the process units;

(E) The emission and operating parameter limitations specified in the relevant standard(s);

(F) The monitoring equipment manufacturer(s) and model number(s);

(G) The date of the latest CMS certification or audit;

(H) The total operating time of the affected source during the reporting period;

(I) An emission data summary (or similar summary if the owner or operator monitors control system parameters), including the total duration of excess emissions during the reporting period (recorded in minutes for opacity and hours for gases), the total duration of excess emissions expressed as a percent of the total source operating time during that reporting period, and a breakdown of the total duration of excess emissions during the reporting period into those that are due to startup/shutdown, control equipment problems, process problems, other known causes, and other unknown causes;

(J) A CMS performance summary (or similar summary if the owner or operator monitors control system parameters), including the total CMS downtime during the reporting period (recorded in minutes for opacity and hours for gases), the total duration of CMS downtime expressed as a percent of the total source operating time during that reporting period, and a breakdown of the total CMS downtime during the reporting period into periods that are due to monitoring equipment malfunctions, nonmonitoring equipment malfunctions, quality assurance/quality control calibrations, other known causes, and other unknown causes;

(K) A description of any changes in CMS, processes, or controls since the last reporting period;

(L) The name, title, and signature of the responsible official who is certifying the accuracy of the report; and

(M) The date of the report.

(vii) If the total duration of excess emissions or process or control system parameter exceedances for the reporting period is less than 1 percent of the total operating time for the reporting period, and CMS downtime


for the reporting period is less than 5 percent of the total operating time for the reporting period, only the summary report shall be submitted, and the full excess emissions and continuous monitoring system performance report need not be submitted unless required by the Administrator.

(viii) If the total duration of excess emissions or process or control system parameter exceedances for the reporting period is 1 percent or greater of the total operating time for the reporting period, or the total CMS downtime for the reporting period is 5 percent or greater of the total operating time for the reporting period, both the summary report and the excess emissions and continuous monitoring system performance report shall be submitted.

(4) Reporting continuous opacity monitoring system data produced during a performance test. The owner or operator of an affected source required to use a COMS shall record the monitoring data produced during a performance test required under §63.7 and shall furnish the Administrator a written report of the monitoring results. The report of COMS data shall be submitted simultaneously with the report of the performance test results required in paragraph (d)(2) of this section.

(f) Waiver of recordkeeping or reporting requirements.

(1) Until a waiver of a recordkeeping or reporting requirement has been granted by the Administrator under this paragraph, the owner or operator of an affected source remains subject to the requirements of this section.

(2) Recordkeeping or reporting requirements may be waived upon written application to the Administrator if, in the Administrator's judgment, the affected source is achieving the relevant standard(s), or the source is operating under an extension of compliance, or the owner or operator has requested an extension of compliance and the Administrator is still considering that request.

(3) If an application for a waiver of recordkeeping or reporting is made, the application shall accompany the request for an extension of compliance under §63.6(i), any required compliance progress report or compliance status report required under this part (such as under §§63.6(i) and 63.9(h)) or in the source's title V permit, or an excess emissions and continuous monitoring system performance report required under paragraph (e) of this section, whichever is applicable. The application shall include whatever information the owner or operator considers useful to convince the Administrator that a waiver of recordkeeping or reporting is warranted.

(4) The Administrator will approve or deny a request for a waiver of recordkeeping or reporting requirements under this paragraph when he/she—

(i) Approves or denies an extension of compliance; or

(ii) Makes a determination of compliance following the submission of a required compliance status report or excess emissions and continuous monitoring systems performance report; or

(iii) Makes a determination of suitable progress towards compliance following the submission of a compliance progress report, whichever is applicable.

(5) A waiver of any recordkeeping or reporting requirement granted under this paragraph may be conditioned on other recordkeeping or reporting requirements deemed necessary by the Administrator.

(6) Approval of any waiver granted under this section shall not abrogate the Administrator's authority under the Act or in any way prohibit the Administrator from later canceling the waiver. The cancellation will be made only after notice is given to the owner or operator of the affected source.

§63.11 Control device and work practice requirements.

(a) Applicability.



(2) This section contains requirements for control devices used to comply with applicable subparts of this part. The requirements are placed here for administrative convenience and apply only to facilities covered by subparts referring to this section.

(3) This section also contains requirements for an alternative work practice used to identify leaking equipment. This alternative work practice is placed here for administrative convenience and is available to all subparts in 40 CFR parts 60, 61, 63, and 65 that require monitoring of equipment with a 40 CFR part 60, appendix A-7, Method 21 monitor.

(b) Flares.

(1) Owners or operators using flares to comply with the provisions of this part shall monitor these control devices to assure that they are operated and maintained in conformance with their designs. Applicable subparts will provide provisions stating how owners or operators using flares shall monitor these control devices.

(2) Flares shall be steam-assisted, air-assisted, or non-assisted.

(3) Flares shall be operated at all times when emissions may be vented to them.

(4) Flares shall be designed for and operated with no visible emissions, except for periods not to exceed a total of 5 minutes during any 2 consecutive hours. Test Method 22 in appendix A of part 60 of this chapter shall be used to determine the compliance of flares with the visible emission provisions of this part. The observation period is 2 hours and shall be used according to Method 22.

(5) Flares shall be operated with a flame present at all times. The presence of a flare pilot flame shall be monitored using a thermocouple or any other equivalent device to detect the presence of a flame.

(6) An owner/operator has the choice of adhering to the heat content specifications in paragraph (b)(6)(ii) of this section, and the maximum tip velocity specifications in paragraph (b)(7) or (b)(8) of this section, or adhering to the requirements in paragraph (b)(6)(i) of this section.

(i)(A) Flares shall be used that have a diameter of 3 inches or greater, are nonassisted, have a hydrogen content of 8.0 percent (by volume) or greater, and are designed for and operated with an exit velocity less than 37.2 m/sec (122 ft/sec) and less than the velocity Vmax, as determined by the following equation:

Vmax = (XH2−K1)* K2

Where:

Vmax = Maximum permitted velocity, m/sec.

K1 = Constant, 6.0 volume-percent hydrogen.

K2 = Constant, 3.9(m/sec)/volume-percent hydrogen.

XH2 = The volume-percent of hydrogen, on a wet basis, as calculated by using the American Society for Testing and Materials (ASTM) Method D1946-77. (Incorporated by reference as specified in §63.14).

(B) The actual exit velocity of a flare shall be determined by the method specified in paragraph (b)(7)(i) of this section.

(ii) Flares shall be used only with the net heating value of the gas being combusted at 11.2 MJ/scm (300 Btu/scf) or greater if the flare is steam-assisted or air-assisted; or with the net heating value of the gas being combusted at 7.45 M/scm (200 Btu/scf) or greater if the flares is non-assisted. The net heating value of the gas being combusted in a flare shall be calculated using the following equation:


Where:

HT = Net heating value of the sample, MJ/scm; where the net enthalpy per mole of offgas is based on combustion at 25 °C and 760 mm Hg, but the standard temperature for determining the volume corresponding to one mole is 20 °C.

K = Constant =

where the standard temperature for (g-mole/scm) is 20 °C.

Ci = Concentration of sample component i in ppmv on a wet basis, as measured for organics by Test Method 18 and measured for hydrogen and carbon monoxide by American Society for Testing and Materials (ASTM) D1946-77 or 90 (Reapproved 1994) (incorporated by reference as specified in §63.14).

Hi = Net heat of combustion of sample component i, kcal/g-mole at 25 °C and 760 mm Hg. The heats of combustion may be determined using ASTM D2382-76 or 88 or D4809-95 (incorporated by reference as specified in §63.14) if published values are not available or cannot be calculated.

n = Number of sample components.

(7)(i) Steam-assisted and nonassisted flares shall be designed for and operated with an exit velocity less than 18.3 m/sec (60 ft/sec), except as provided in paragraphs (b)(7)(ii) and (b)(7)(iii) of this section. The actual exit velocity of a flare shall be determined by dividing by the volumetric flow rate of gas being combusted (in units of emission standard temperature and pressure), as determined by Test Method 2, 2A, 2C, or 2D in appendix A to 40 CFR part 60 of this chapter, as appropriate, by the unobstructed (free) cross-sectional area of the flare tip.

(ii) Steam-assisted and nonassisted flares designed for and operated with an exit velocity, as determined by the method specified in paragraph (b)(7)(i) of this section, equal to or greater than 18.3 m/sec (60 ft/sec) but less than 122 m/sec (400 ft/sec), are allowed if the net heating value of the gas being combusted is greater than 37.3 MJ/scm (1,000 Btu/scf).

(iii) Steam-assisted and nonassisted flares designed for and operated with an exit velocity, as determined by the method specified in paragraph (b)(7)(i) of this section, less than the velocity Vmax, as determined by the method specified in this paragraph, but less than 122 m/sec (400 ft/sec) are allowed. The maximum permitted velocity, Vmax, for flares complying with this paragraph shall be determined by the following equation:

Log10(Vmax) = (HT + 28.8)/31.7

Where:


28.8 = Constant.

31.7 = Constant.

HT = The net heating value as determined in paragraph (b)(6) of this section.

(8) Air-assisted flares shall be designed and operated with an exit velocity less than the velocity Vmax. The maximum permitted velocity, Vmax, for air-assisted flares shall be determined by the following equation:


Vmax = 8.71 + 0.708(HT)

Where:


8.71 = Constant.

0.708 = Constant.

HT = The net heating value as determined in paragraph (b)(6)(ii) of this section.

(c) Alternative work practice for monitoring equipment for leaks. Paragraphs (c), (d), and (e) of this section apply to all equipment for which the applicable subpart requires monitoring with a 40 CFR part 60, appendix A-7, Method 21 monitor, except for closed vent systems, equipment designated as leakless, and equipment identified in the applicable subpart as having no detectable emissions, as indicated by an instrument reading of less than 500 ppm above background. An owner or operator may use an optical gas imaging instrument instead of a 40 CFR part 60, sppendix A-7, Method 21 monitor. Requirements in the existing subparts that are specific to the Method 21 instrument do not apply under this section. All other requirements in the applicable subpart that are not addressed in paragraphs (c), (d), and (e) of this section continue to apply. For example, equipment specification requirements, and non-Method 21 instrument recordkeeping and reporting requirements in the applicable subpart continue to apply. The terms defined in paragraphs (c)(1) through (5) of this section have meanings that are specific to the alternative work practice standard in paragraphs (c), (d), and (e) of this section.

(1) Applicable subpart means the subpart in 40 CFR parts 60, 61, 63, and 65 that requires monitoring of equipment with a 40 CFR part 60, appendix A-7, Method 21 monitor.

(2) Equipment means pumps, valves, pressure relief valves, compressors, open-ended lines, flanges, connectors, and other equipment covered by the applicable subpart that require monitoring with a 40 CFR part 60, appendix A-7, Method 21 monitor.

(3) Imaging means making visible emissions that may otherwise be invisible to the naked eye.

(4) Optical gas imaging instrument means an instrument that makes visible emissions that may otherwise be invisible to the naked eye.

(5) Repair means that equipment is adjusted, or otherwise altered, in order to eliminate a leak.

(6) Leak means:

(i) Any emissions imaged by the optical gas instrument;

(ii) Indications of liquids dripping;

(iii) Indications by a sensor that a seal or barrier fluid system has failed; or

(iv) Screening results using a 40 CFR part 60, appendix A-7, Method 21 monitor that exceed the leak definition in the applicable subpart to which the equipment is subject.

(d) The alternative work practice standard for monitoring equipment for leaks is available to all subparts in 40 CFR parts 60, 61, 63, and 65 that require monitoring of equipment with a 40 CFR part 60, appendix A-7, Method 21 monitor.

(1) An owner or operator of an affected source subject to 40 CFR parts 60, 61, 63, or 65 can choose to comply with the alternative work practice requirements in paragraph (e) of this section instead of using the 40 CFR part 60, appendix A-7, Method 21 monitor to identify leaking equipment. The owner or operator must document the equipment, process units, and facilities for which the alternative work practice will be used to identify leaks.

(2) Any leak detected when following the leak survey procedure in paragraph (e)(3) of this section must be identified for repair as required in the applicable subpart.


(3) If the alternative work practice is used to identify leaks, re-screening after an attempted repair of leaking equipment must be conducted using either the alternative work practice or the 40 CFR part 60, Appendix A-7, Method 21 monitor at the leak definition required in the applicable subparts to which the equipment is subject.

(4) The schedule for repair is as required in the applicable subpart.

(5) When this alternative work practice is used for detecting leaking equipment, choose one of the monitoring frequencies listed in Table 1 to subpart A of this part in lieu of the monitoring frequency specified for regulated equipment in the applicable subpart. Reduced monitoring frequencies for good performance are not applicable when using the alternative work practice.

(6) When this alternative work practice is used for detecting leaking equipment, the following are not applicable for the equipment being monitored:

(i) Skip period leak detection and repair;

(ii) Quality improvement plans; or

(iii) Complying with standards for allowable percentage of valves and pumps to leak.

(7) When the alternative work practice is used to detect leaking equipment, the regulated equipment in paragraph (d)(1)(i) of this section must also be monitored annually using a 40 CFR part 60, Appendix A-7, Method 21 monitor at the leak definition required in the applicable subpart. The owner or operator may choose the specific monitoring period (for example, first quarter) to conduct the annual monitoring. Subsequent monitoring must be conducted every 12 months from the initial period. Owners or operators must keep records of the annual Method 21 screening results, as specified in paragraph (i)(4)(vii) of this section.

(e) An owner or operator of an affected source who chooses to use the alternative work practice must comply with the requirements of paragraphs (e)(1) through (e)(5) of this section.

(1) Instrument specifications. The optical gas imaging instrument must comply with the requirements specified in paragraphs (e)(1)(i) and (e)(1)(ii) of this section.

(i) Provide the operator with an image of the potential leak points for each piece of equipment at both the detection sensitivity level and within the distance used in the daily instrument check described in paragraph (e)(2) of this section. The detection sensitivity level depends upon the frequency at which leak monitoring is to be performed.

(ii) Provide a date and time stamp for video records of every monitoring event.

(2) Daily instrument check. On a daily basis, and prior to beginning any leak monitoring work, test the optical gas imaging instrument at the mass flow rate determined in paragraph (e)(2)(i) of this section in accordance with the procedure specified in paragraphs (e)(2)(ii) through (e)(2)(iv) of this section for each camera configuration used during monitoring (for example, different lenses used), unless an alternative method to demonstrate daily instrument checks has been approved in accordance with paragraph (e)(2)(v) of this section.

(i) Calculate the mass flow rate to be used in the daily instrument check by following the procedures in paragraphs (e)(2)(i)(A) and (e)(2)(i)(B) of this section.

(A) For a specified population of equipment to be imaged by the instrument, determine the piece of equipment in contact with the lowest mass fraction of chemicals that are detectable, within the distance to be used in paragraph (e)(2)(iv)(B) of this section, at or below the standard detection sensitivity level.

(B) Multiply the standard detection sensitivity level, corresponding to the selected monitoring frequency in Table 1 of subpart A of this part, by the mass fraction of detectable chemicals from the


stream identified in paragraph (e)(2)(i)(A) of this section to determine the mass flow rate to be used in the daily instrument check, using the following equation.

Where:

Edic = Mass flow rate for the daily instrument check, grams per hour

xi = Mass fraction of detectable chemical(s) i seen by the optical gas imaging instrument, within the distance to be used in paragraph (e)(2)(iv)(B) of this section, at or below the standard detection sensitivity level, Esds.

Esds = Standard detection sensitivity level from Table 1 to subpart A, grams per hour

k = Total number of detectable chemicals emitted from the leaking equipment and seen by the optical gas imaging instrument.

(ii) Start the optical gas imaging instrument according to the manufacturer's instructions, ensuring that all appropriate settings conform to the manufacturer's instructions.

(iii) Use any gas chosen by the user that can be viewed by the optical gas imaging instrument and that has a purity of no less than 98 percent.

(iv) Establish a mass flow rate by using the following procedures:

(A) Provide a source of gas where it will be in the field of view of the optical gas imaging instrument.

(B) Set up the optical gas imaging instrument at a recorded distance from the outlet or leak orifice of the flow meter that will not be exceeded in the actual performance of the leak survey. Do not exceed the operating parameters of the flow meter.

(C) Open the valve on the flow meter to set a flow rate that will create a mass emission rate equal to the mass rate calculated in paragraph (e)(2)(i) of this section while observing the gas flow through the optical gas imaging instrument viewfinder. When an image of the gas emission is seen through the viewfinder at the required emission rate, make a record of the reading on the flow meter.

(v) Repeat the procedures specified in paragraphs (e)(2)(ii) through (e)(2)(iv) of this section for each configuration of the optical gas imaging instrument used during the leak survey.

(vi) To use an alternative method to demonstrate daily instrument checks, apply to the Administrator for approval of the alternative under §63.177 or §63.178, whichever is applicable.

(3) Leak survey procedure. Operate the optical gas imaging instrument to image every regulated piece of equipment selected for this work practice in accordance with the instrument manufacturer's operating parameters. All emissions imaged by the optical gas imaging instrument are considered to be leaks and are subject to repair. All emissions visible to the naked eye are also considered to be leaks and are subject to repair.

(4) Recordkeeping. Keep the records described in paragraphs (e)(4)(i) through (e)(4)(vii) of this section:

(i) The equipment, processes, and facilities for which the owner or operator chooses to use the alternative work practice.

(ii) The detection sensitivity level selected from Table 1 to subpart A of this part for the optical gas imaging instrument.

(iii) The analysis to determine the piece of equipment in contact with the lowest mass fraction of chemicals that are detectable, as specified in paragraph (e)(2)(i)(A) of this section.


(iv) The technical basis for the mass fraction of detectable chemicals used in the equation in paragraph (e)(2)(i)(B) of this section.

(v) The daily instrument check. Record the distance, per paragraph (e)(2)(iv)(B) of this section, and the flow meter reading, per paragraph (e)(2)(iv)(C) of this section, at which the leak was imaged. Keep a video record of the daily instrument check for each configuration of the optical gas imaging instrument used during the leak survey (for example, the daily instrument check must be conducted for each lens used). The video record must include a time and date stamp for each daily instrument check. The video record must be kept for 5 years.

(vi) Recordkeeping requirements in the applicable subpart. A video record must be used to document the leak survey results. The video record must include a time and date stamp for each monitoring event. A video record can be used to meet the recordkeeping requirements of the applicable subparts if each piece of regulated equipment selected for this work practice can be identified in the video record. The video record must be kept for 5 years.

(vii) The results of the annual Method 21 screening required in paragraph (h)(7) of this section. Records must be kept for all regulated equipment specified in paragraph (h)(1) of this section. Records must identify the equipment screened, the screening value measured by Method 21, the time and date of the screening, and calibration information required in the existing applicable subparts.

(5) Reporting. Submit the reports required in the applicable subpart. Submit the records of the annual Method 21 screening required in paragraph (h)(7) of this section to the Administrator via e-mail to [email protected].

§63.12 State authority and delegations.

(a) The provisions of this part shall not be construed in any manner to preclude any State or political subdivision thereof from—

(1) Adopting and enforcing any standard, limitation, prohibition, or other regulation applicable to an affected source subject to the requirements of this part, provided that such standard, limitation, prohibition, or regulation is not less stringent than any requirement applicable to such source established under this part;

(2) Requiring the owner or operator of an affected source to obtain permits, licenses, or approvals prior to initiating construction, reconstruction, modification, or operation of such source; or

(3) Requiring emission reductions in excess of those specified in subpart D of this part as a condition for granting the extension of compliance authorized by section 112(i)(5) of the Act.

(b)(1) Section 112(l) of the Act directs the Administrator to delegate to each State, when appropriate, the authority to implement and enforce standards and other requirements pursuant to section 112 for stationary sources located in that State. Because of the unique nature of radioactive material, delegation of authority to implement and enforce standards that control radionuclides may require separate approval.

(2) Subpart E of this part establishes procedures consistent with section 112(l) for the approval of State rules or programs to implement and enforce applicable Federal rules promulgated under the authority of section 112. Subpart E also establishes procedures for the review and withdrawal of section 112 implementation and enforcement authorities granted through a section 112(l) approval.

(c) All information required to be submitted to the EPA under this part also shall be submitted to the appropriate State agency of any State to which authority has been delegated under section 112(l) of the Act, provided that each specific delegation may exempt sources from a certain Federal or State reporting requirement. The Administrator may permit all or some of the information to be submitted to the appropriate State agency only, instead of to the EPA and the State agency.



§63.13 Addresses of State air pollution control agencies and EPA Regional Offices.

(a) All requests, reports, applications, submittals, and other communications to the Administrator pursuant to this part shall be submitted to the appropriate Regional Office of the U.S. Environmental Protection Agency indicated in the following list of EPA Regional Offices.

EPA Region I (Connecticut, Maine, Massachusetts, New Hampshire, Rhode Island, Vermont), Director, Office of Ecosystem Protection, 5 Post Office Square—Suite 100, Boston, MA 02109-3912.

EPA Region II (New Jersey, New York, Puerto Rico, Virgin Islands), Director, Air and Waste Management Division, 26 Federal Plaza, New York, NY 10278.

EPA Region III (Delaware, District of Columbia, Maryland, Pennsylvania, Virginia, West Virginia), Director, Air Protection Division, 1650 Arch Street, Philadelphia, PA 19103.

EPA Region IV (Alabama, Florida, Georgia, Kentucky, Mississippi, North Carolina, South Carolina, Tennessee). Director, Air, Pesticides and Toxics Management Division, Atlanta Federal Center, 61 Forsyth Street, Atlanta, GA 30303-3104.

EPA Region V (Illinois, Indiana, Michigan, Minnesota, Ohio, Wisconsin), Director, Air and Radiation Division, 77 West Jackson Blvd., Chicago, IL 60604-3507.

EPA Region VI (Arkansas, Louisiana, New Mexico, Oklahoma, Texas), Director, Air, Pesticides and Toxics, 1445 Ross Avenue, Dallas, TX 75202-2733.

EPA Region VII (Iowa, Kansas, Missouri, Nebraska), Director, Air and Waste Management Division, 11201 Renner Boulevard, Lenexa, Kansas 66219.

EPA Region VIII (Colorado, Montana, North Dakota, South Dakota, Utah, Wyoming) Director, Air and Toxics Technical Enforcement Program, Office of Enforcement, Compliance and Environmental Justice, Mail Code 8ENF-AT, 1595 Wynkoop Street, Denver, CO 80202-1129.

EPA Region IX (Arizona, California, Hawaii, Nevada; the territories of American Samoa and Guam; the Commonwealth of the Northern Mariana Islands; the territories of Baker Island, Howland Island, Jarvis Island, Johnston Atoll, Kingman Reef, Midway Atoll, Palmyra Atoll, and Wake Islands; and certain U.S. Government activities in the freely associated states of the Republic of the Marshall Islands, the Federated States of Micronesia, and the Republic of Palau), Director, Air Division, 75 Hawthorne Street, San Francisco, CA 94105.

EPA Region X (Alaska, Idaho, Oregon, Washington), Director, Office of Air Quality, 1200 Sixth Avenue (OAQ-107), Seattle, WA 98101.

(b) All information required to be submitted to the Administrator under this part also shall be submitted to the appropriate State agency of any State to which authority has been delegated under section 112(l) of the Act. The owner or operator of an affected source may contact the appropriate EPA Regional Office for the mailing addresses for those States whose delegation requests have been approved.

(c) If any State requires a submittal that contains all the information required in an application, notification, request, report, statement, or other communication required in this part, an owner or operator may send the appropriate Regional Office of the EPA a copy of that submittal to satisfy the requirements of this part for that communication.

§63.14 Incorporations by reference.

(a) Certain material is incorporated by reference into this part with the approval of the Director of the Federal Register under 5 U.S.C. 552(a) and 1 CFR part 51. To enforce any edition other than that specified in this section, the EPA must publish notice of change in the Federal Register and the material must be available to the public. All approved material is available for inspection at the Air and Radiation Docket and Information Center, U.S. EPA, 401 M St. SW., Washington, DC,


telephone number 202-566, and is available from the sources listed below. It is also available for inspection at the National Archives and Records Administration (NARA). For information on the availability of this material at NARA, call 202-741-6030 or go to http://www.archives.gov/federal_register/code_of_federal_regulations/ibr_locations.html.

(b) American Conference of Governmental Industrial Hygienists (ACGIH), Customer Service Department, 1330 Kemper Meadow Drive, Cincinnati, Ohio 45240, telephone number (513) 742-2020.

(1) Industrial Ventilation: A Manual of Recommended Practice, 22nd Edition, 1995, Chapter 3, “Local Exhaust Hoods” and Chapter 5, “Exhaust System Design Procedure.” IBR approved for §§63.843(b) and 63.844(b).

(2) Industrial Ventilation: A Manual of Recommended Practice, 23rd Edition, 1998, Chapter 3, “Local Exhaust Hoods” and Chapter 5, “Exhaust System Design Procedure.” IBR approved for §§63.1503, 63.1506(c), 63.1512(e), Table 2 to Subpart RRR, Table 3 to Subpart RRR, and Appendix A to Subpart RRR.

(3) Industrial Ventilation: A Manual of Recommended Practice for Design, 27th Edition, 2010. IBR approved for §§63.1503, 63.1506(c), 63.1512(e), Table 2 to Subpart RRR, Table 3 to Subpart RRR, and Appendix A to Subpart RRR.

(c) The Association of Florida Phosphate Chemists, P.O. Box 1645, Bartow, Florida 33830.

(1) Book of Methods Used and Adopted By The Association of Florida Phosphate Chemists, Seventh Edition 1991:

(i) Section IX, Methods of Analysis for Phosphate Rock, No. 1 Preparation of Sample, IBR approved for §63.606(f), §63.626(f).

(ii) Section IX, Methods of Analysis for Phosphate Rock, No. 3 Phosphorus-P2O5 or Ca3(PO4)2, Method A—Volumetric Method, IBR approved for §63.606(f), §63.626(f).

(iii) Section IX, Methods of Analysis for Phosphate Rock, No. 3 Phosphorus-P2O5 or Ca3(PO4)2, Method B—Gravimetric Quimociac Method, IBR approved for §63.606(f), §63.626(f).

(iv) Section IX, Methods of Analysis For Phosphate Rock, No. 3 Phosphorus-P2O5 or Ca3(PO4)2, Method C—Spectrophotometric Method, IBR approved for §63.606(f), §63.626(f).

(v) Section XI, Methods of Analysis for Phosphoric Acid, Superphosphate, Triple Superphosphate, and Ammonium Phosphates, No. 3 Total Phosphorus-P2O5, Method A—Volumetric Method, IBR approved for §63.606(f), §63.626(f), and (g).

(vi) Section XI, Methods of Analysis for Phosphoric Acid, Superphosphate, Triple Superphosphate, and Ammonium Phosphates, No. 3 Total Phosphorus-P2O5, Method B—Gravimetric Quimociac Method, IBR approved for §63.606(f), §63.626(f), and (g).

(vii) Section XI, Methods of Analysis for Phosphoric Acid, Superphosphate, Triple Superphosphate, and Ammonium Phosphates, No. 3 Total Phosphorus-P2O5, Method C—Spectrophotometric Method, IBR approved for §63.606(f), §63.626(f), and (g).

(2) [Reserved]

(d) Association of Official Analytical Chemists (AOAC) International, Customer Services, Suite 400, 2200 Wilson Boulevard, Arlington, Virginia 22201-3301, Telephone (703) 522-3032, Fax (703) 522-5468.

(1) AOAC Official Method 929.01 Sampling of Solid Fertilizers, Sixteenth edition, 1995, IBR approved for §63.626(g).

(2) AOAC Official Method 929.02 Preparation of Fertilizer Sample, Sixteenth edition, 1995, IBR approved for §63.626(g).

(3) AOAC Official Method 957.02 Phosphorus (Total) in Fertilizers, Preparation of Sample Solution, Sixteenth edition, 1995, IBR approved for §63.626(g).

(4) AOAC Official Method 958.01 Phosphorus (Total) in Fertilizers, Spectrophotometric Molybdovanadophosphate Method, Sixteenth edition, 1995, IBR approved for §63.626(g).


(5) AOAC Official Method 962.02 Phosphorus (Total) in Fertilizers, Gravimetric Quinolinium Molybdophosphate Method, Sixteenth edition, 1995, IBR approved for §63.626(g).

(6) AOAC Official Method 969.02 Phosphorus (Total) in Fertilizers, Alkalimetric Quinolinium Molybdophosphate Method, Sixteenth edition, 1995, IBR approved for §63.626(g).

(7) AOAC Official Method 978.01 Phosphorus (Total) in Fertilizers, Automated Method, Sixteenth edition, 1995, IBR approved for §63.626(g).

(e) American Petroleum Institute (API), 1220 L Street NW., Washington, DC 20005.

(1) API Publication 2517, Evaporative Loss from External Floating-Roof Tanks, Third Edition, February 1989, IBR approved for §§63.111 and 63.2406.

(2) API Publication 2518, Evaporative Loss from Fixed-roof Tanks, Second Edition, October 1991, IBR approved for §63.150(g).

(3) API Manual of Petroleum Measurement Specifications (MPMS) Chapter 19.2 (API MPMS 19.2), Evaporative Loss From Floating-Roof Tanks, First Edition, April 1997, IBR approved for §§63.1251 and 63.12005.

(f) American Society of Heating, Refrigerating, and Air-Conditioning Engineers at 1791 Tullie Circle, NE., Atlanta, GA 30329 [email protected].

(1) American Society of Heating, Refrigerating, and Air Conditioning Engineers Method 52.1, “Gravimetric and Dust-Spot Procedures for Testing Air-Cleaning Devices Used in General Ventilation for Removing Particulate Matter, June 4, 1992,” IBR approved for §§63.11173(e) and 63.11516(d).

(2) [Reserved]

(g) American Society of Mechanical Engineers (ASME), Three Park Avenue, New York, NY 10016-5990, Telephone (800) 843-2763, http://www.asme.org; also available from HIS, Incorporated, 15 Inverness Way East, Englewood, CO 80112, Telephone (877) 413-5184, http://global.ihs.com.

(1) ANSI/ASME PTC 19.10-1981, Flue and Exhaust Gas Analyses [Part 10, Instruments and Apparatus], issued August 31, 1981, IBR approved for §§63.309(k), 63.457(k), 63.772(e) and (h), 63.865(b), 63.1282(d) and (g), 63.1625(b), 63.3166(a), 63.3360(e), 63.3545(a), 63.3555(a), 63.4166(a), 63.4362(a), 63.4766(a), 63.4965(a), 63.5160(d), table 4 to subpart UUUU, 63.9307(c), 63.9323(a), 63.11148(e), 63.11155(e), 63.11162(f), 63.11163(g), 63.11410(j), 63.11551(a), 63.11646(a), and 63.11945, table 5 to subpart DDDDD, table 4 to subpart JJJJJ, table 4 to subpart KKKKK, tables 4 and 5 of subpart UUUUU, table 1 to subpart ZZZZZ, and table 4 to subpart JJJJJJ.

(2) [Reserved]

(h) American Society for Testing and Materials (ASTM), 100 Barr Harbor Drive, Post Office Box C700, West Conshohocken, PA 19428-2959, Telephone (610) 832-9585, http://www.astm.org; also available from ProQuest, 789 East Eisenhower Parkway, Ann Arbor, MI 48106-1346, Telephone (734) 761-4700, http://www.proquest.com.

(1) ASTM D95-05 (Reapproved 2010), Standard Test Method for Water in Petroleum Products and Bituminous Materials by Distillation, approved May 1, 2010, IBR approved for §63.10005(i) and table 6 to subpart DDDDD.

(2) ASTM D240-09 Standard Test Method for Heat of Combustion of Liquid Hydrocarbon Fuels by Bomb Calorimeter, approved July 1, 2009, IBR approved for table 6 to subpart DDDDD.

(3) ASTM Method D388-05, Standard Classification of Coals by Rank, approved September 15, 2005, IBR approved for §§63.7575, 63.10042, and 63.11237.

(4) ASTM Method D396-10, Standard Specification for Fuel Oils, including Appendix X1, approved October 1, 2010, IBR approved for §63.10042.


(5) ASTM D396-10, Standard Specification for Fuel Oils, approved October 1, 2010, IBR approved for §§63.7575 and 63.11237.

(6) ASTM D523-89, Standard Test Method for Specular Gloss, IBR approved for §63.782.

(7) ASTM D975-11b, Standard Specification for Diesel Fuel Oils, approved December 1, 2011, IBR approved for §63.7575.

(8) ASTM D1193-77, Standard Specification for Reagent Water, IBR approved for appendix A to part 63: Method 306, Sections 7.1.1 and 7.4.2.

(9) ASTM D1193-91, Standard Specification for Reagent Water, IBR approved for appendix A to part 63: Method 306, Sections 7.1.1 and 7.4.2.

(10) ASTM D1331-89, Standard Test Methods for Surface and Interfacial Tension of Solutions of Surface Active Agents, IBR approved for appendix A to part 63: Method 306B, Sections 6.2, 11.1, and 12.2.2.

(11) ASTM D1475-90, Standard Test Method for Density of Paint, Varnish Lacquer, and Related Products, IBR approved for appendix A to subpart II.

(12) ASTM D1475-98 (Reapproved 2003), “Standard Test Method for Density of Liquid Coatings, Inks, and Related Products,” IBR approved for §§63.3151(b), 63.3941(b) and (c), 63.3951(c), 63.4141(b) and (c), and 63.4551(c).

(13) ASTM Method D1835-05, Standard Specification for Liquefied Petroleum (LP) Gases, approved April 1, 2005, IBR approved for §§63.7575 and 63.11237.

(14) ASTM D1945-03 (Reapproved 2010), Standard Test Method for Analysis of Natural Gas by Gas Chromatography, Approved January 1, 2010, IBR approved for §§63.670(j), 63.772(h), and 63.1282(g).

(15) ASTM D1945-14, Standard Test Method for Analysis of Natural Gas by Gas Chromatography, Approved November 1, 2014, IBR approved for §63.670(j).

(16) ASTM D1946-77, Standard Method for Analysis of Reformed Gas by Gas Chromatography, IBR approved for §63.11(b).

(17) ASTM D1946-90 (Reapproved 1994), Standard Method for Analysis of Reformed Gas by Gas Chromatography, IBR approved for §63.11(b).

(18) ASTM D2013/D2013M-09, Standard Practice for Preparing Coal Samples for Analysis, (Approved November 1, 2009), IBR approved for table 6 to subpart DDDDD and table 5 to subpart JJJJJJ.

(19) ASTM D2099-00, Standard Test Method for Dynamic Water Resistance of Shoe Upper Leather by the Maeser Water Penetration Tester, IBR approved for §63.5350.

(20) ASTM D2216-05, Standard Test Methods for Laboratory Determination of Water (Moisture) Content of Soil and Rock by Mass, IBR approved for the definition of “Free organic liquids” in §63.10692.

(21) ASTM D2234/D2234M-10, Standard Practice for Collection of a Gross Sample of Coal, approved January 1, 2010, IBR approved for table 6 to subpart DDDDD and table 5 to subpart JJJJJJ .

(22) ASTM D2369-93, Standard Test Method for Volatile Content of Coatings, IBR approved for appendix A to subpart II.

(23) ASTM D2369-95, Standard Test Method for Volatile Content of Coatings, IBR approved for appendix A to subpart II.

(24) ASTM D2382-76, Heat of Combustion of Hydrocarbon Fuels by Bomb Calorimeter (High-Precision Method), IBR approved for §63.11(b).

(25) ASTM D2382-88, Heat of Combustion of Hydrocarbon Fuels by Bomb Calorimeter (High-Precision Method), IBR approved for §63.11(b).


(26) ASTM D2697-86 (Reapproved 1998), Standard Test Method for Volume Nonvolatile Matter in Clear or Pigmented Coatings, IBR approved for §§63.3161(f), 63.3521(b), 63.3941(b), 63.4141(b), 63.4741(b), 63.4941(b), and 63.5160(c).

(27) ASTM D2879-83, Standard Method for Vapor Pressure-Temperature Relationship and Initial Decomposition Temperature of Liquids by Isoteniscope, IBR approved for §§63.111, 63.2406, and 63.12005.

(28) ASTM D2879-96, Test Method for Vapor Pressure-Temperature Relationship and Initial Decomposition Temperature of Liquids by Isoteniscope, (Approved 1996), IBR approved for §§63.111, 63.2406, and 63.12005.

(29) ASTM D2908-74, Standard Practice for Measuring Volatile Organic Matter in Water by Aqueous-Injection Gas Chromatography, Approved June 27, 1974, IBR approved for §63.1329(c).

(30) ASTM D2908-91, Standard Practice for Measuring Volatile Organic Matter in Water by Aqueous-Injection Gas Chromatography, Approved December 15, 1991, IBR approved for §63.1329(c).

(31) ASTM D2908-91(Reapproved 2001), Standard Practice for Measuring Volatile Organic Matter in Water by Aqueous-Injection Gas Chromatography, Approved December 15, 1991, IBR approved for §63.1329(c).

(32) ASTM D2908-91(Reapproved 2005), Standard Practice for Measuring Volatile Organic Matter in Water by Aqueous-Injection Gas Chromatography, Approved December 1, 2005, IBR approved for §63.1329(c).

(33) ASTM D2908-91(Reapproved 2011), Standard Practice for Measuring Volatile Organic Matter in Water by Aqueous-Injection Gas Chromatography, Approved May 1, 2011, IBR approved for §63.1329(c).

(34) ASTM D2986-95A, “Standard Practice for Evaluation of Air Assay Media by the Monodisperse DOP (Dioctyl Phthalate) Smoke Test,” approved September 10, 1995, IBR approved for section 7.1.1 of Method 315 in appendix A to this part.

(35) ASTM D3173-03 (Reapproved 2008), Standard Test Method for Moisture in the Analysis Sample of Coal and Coke, (Approved February 1, 2008), IBR approved for table 6 to subpart DDDDD and table 5 to subpart JJJJJJ.

(36) ASTM D3257-93, Standard Test Methods for Aromatics in Mineral Spirits by Gas Chromatography, IBR approved for §63.786(b).

(37) ASTM D3370-76, Standard Practices for Sampling Water, Approved August 27, 1976, IBR approved for §63.1329(c).

(38) ASTM D3370-95a, Standard Practices for Sampling Water from Closed Conduits, Approved September 10, 1995, IBR approved for §63.1329(c).

(39) ASTM D3370-07, Standard Practices for Sampling Water from Closed Conduits, Approved December 1, 2007, IBR approved for §63.1329(c).

(40) ASTM D3370-08, Standard Practices for Sampling Water from Closed Conduits, Approved October 1, 2008, IBR approved for §63.1329(c).

(41) ASTM D3370-10, Standard Practices for Sampling Water from Closed Conduits, Approved December 1, 2010, IBR approved for §63.1329(c).

(42) ASTM D3588-98 (Reapproved 2003), Standard Practice for Calculating Heat Value, Compressibility Factor, and Relative Density of Gaseous Fuels, (Approved May 10, 2003), IBR approved for §§63.772(h) and 63.1282(g).

(43) ASTM D3695-88, Standard Test Method for Volatile Alcohols in Water by Direct Aqueous-Injection Gas Chromatography, IBR approved for §63.365(e).

(44) ASTM D3792-91, Standard Method for Water Content of Water-Reducible Paints by Direct Injection into a Gas Chromatograph, IBR approved for appendix A to subpart II.

(45) ASTM D3912-80, Standard Test Method for Chemical Resistance of Coatings Used in Light-Water Nuclear Power Plants, IBR approved for §63.782.


(46) ASTM D4006-11, Standard Test Method for Water in Crude Oil by Distillation, including Annex A1 and Appendix X1, (Approved June 1, 2011), IBR approved for §63.10005(i) and table 6 to subpart DDDDD.

(47) ASTM D4017-81, Standard Test Method for Water in Paints and Paint Materials by the Karl Fischer Titration Method, IBR approved for appendix A to subpart II.

(48) ASTM D4017-90, Standard Test Method for Water in Paints and Paint Materials by the Karl Fischer Titration Method, IBR approved for appendix A to subpart II.

(49) ASTM D4017-96a, Standard Test Method for Water in Paints and Paint Materials by the Karl Fischer Titration Method, IBR approved for appendix A to subpart II.

(50) ASTM D4057-06 (Reapproved 2011), Standard Practice for Manual Sampling of Petroleum and Petroleum Products, including Annex A1, (Approved June 1, 2011), IBR approved for §63.10005(i) and table 6 to subpart DDDDD.

(51) ASTM D4082-89, Standard Test Method for Effects of Gamma Radiation on Coatings for Use in Light-Water Nuclear Power Plants, IBR approved for §63.782.

(52) ASTM D4084-07, Standard Test Method for Analysis of Hydrogen Sulfide in Gaseous Fuels (Lead Acetate Reaction Rate Method), (Approved June 1, 2007), IBR approved for table 6 to subpart DDDDD.

(53) ASTM D4177-95 (Reapproved 2010), Standard Practice for Automatic Sampling of Petroleum and Petroleum Products, including Annexes A1 through A6 and Appendices X1 and X2, (Approved May 1, 2010), IBR approved for §63.10005(i) and table 6 to subpart DDDDD.

(54) ASTM D4208-02 (Reapproved 2007), Standard Test Method for Total Chlorine in Coal by the Oxygen Bomb Combustion/Ion Selective Electrode Method, approved May 1, 2007, IBR approved for table 6 to subpart DDDDD.

(55) ASTM D4239-14e1, “Standard Test Method for Sulfur in the Analysis Sample of Coal and Coke Using High-Temperature Tube Furnace Combustion,” approved March 1, 2014, IBR approved for §63.849(f).

(56) ASTM D4256-89, Standard Test Method for Determination of the Decontaminability of Coatings Used in Light-Water Nuclear Power Plants, IBR approved for §63.782.

(57) ASTM D4256-89 (Reapproved 94), Standard Test Method for Determination of the Decontaminability of Coatings Used in Light-Water Nuclear Power Plants, IBR approved for §63.782.

(58) ASTM D4606-03 (Reapproved 2007), Standard Test Method for Determination of Arsenic and Selenium in Coal by the Hydride Generation/Atomic Absorption Method, (Approved October 1, 2007), IBR approved for table 6 to subpart DDDDD.

(59) ASTM D4809-95, Standard Test Method for Heat of Combustion of Liquid Hydrocarbon Fuels by Bomb Calorimeter (Precision Method), IBR approved for §63.11(b).

(60) ASTM D4891-89 (Reapproved 2006), Standard Test Method for Heating Value of Gases in Natural Gas Range by Stoichiometric Combustion, (Approved June 1, 2006), IBR approved for §§63.772(h) and 63.1282(g).

(61) ASTM D5066-91 (Reapproved 2001), Standard Test Method for Determination of the Transfer Efficiency Under Production Conditions for Spray Application of Automotive Paints-Weight Basis, IBR approved for §63.3161(g).

(62) ASTM D5087-02, Standard Test Method for Determining Amount of Volatile Organic Compound (VOC) Released from Solventborne Automotive Coatings and Available for Removal in a VOC Control Device (Abatement), IBR approved for §63.3165(e) and appendix A to subpart IIII.

(63) ASTM D5192-09, Standard Practice for Collection of Coal Samples from Core, (Approved June 1, 2009), IBR approved for table 6 to subpart DDDDD.


(64) ASTM D5198-09, Standard Practice for Nitric Acid Digestion of Solid Waste, (Approved February 1, 2009), IBR approved for table 6 to subpart DDDDD and table 5 to subpart JJJJJJ.

(65) ASTM D5228-92, Standard Test Method for Determination of Butane Working Capacity of Activated Carbon, (Reapproved 2005), IBR approved for §63.11092(b).

(66) ASTM D5291-02, Standard Test Methods for Instrumental Determination of Carbon, Hydrogen, and Nitrogen in Petroleum Products and Lubricants, IBR approved for appendix A to subpart MMMM.

(67) ASTM D5790-95, Standard Test Method for Measurement of Purgeable Organic Compounds in Water by Capillary Column Gas Chromatography/Mass Spectrometry, IBR approved for Table 4 to subpart UUUU.

(68) ASTM D5864-11, Standard Test Method for Determining Aerobic Aquatic Biodegradation of Lubricants or Their Components, (Approved March 1, 2011), IBR approved for table 6 to subpart DDDDD.

(69) ASTM D5865-10a, Standard Test Method for Gross Calorific Value of Coal and Coke, (Approved May 1, 2010), IBR approved for table 6 to subpart DDDDD and table 5 to subpart JJJJJJ.

(70) ASTM D5954-98 (Reapproved 2006), Test Method for Mercury Sampling and Measurement in Natural Gas by Atomic Absorption Spectroscopy, (Approved December 1, 2006), IBR approved for table 6 to subpart DDDDD.

(71) ASTM D5965-02, Standard Test Methods for Specific Gravity of Coating Powders, IBR approved for §§63.3151(b) and 63.3951(c).

(72) ASTM D6053-00, Standard Test Method for Determination of Volatile Organic Compound (VOC) Content of Electrical Insulating Varnishes, IBR approved for appendix A to subpart MMMM.

(73 ASTM D6093-97 (Reapproved 2003), Standard Test Method for Percent Volume Nonvolatile Matter in Clear or Pigmented Coatings Using a Helium Gas Pycnometer, IBR approved for §§63.3161, 63.3521, 63.3941, 63.4141, 63.4741(b), 63.4941(b), and 63.5160(c).

(74) ASTM D6196-03 (Reapproved 2009), Standard Practice for Selection of Sorbents, Sampling, and Thermal Desorption Analysis Procedures for Volatile Organic Compounds in Air, Approved March 1, 2009, IBR approved for appendix A to this part: Method 325A and Method 325B.

(75) ASTM D6266-00a, Test Method for Determining the Amount of Volatile Organic Compound (VOC) Released from Waterborne Automotive Coatings and Available for Removal in a VOC Control Device (Abatement), IBR approved for §63.3165(e).

(76) ASTM D6323-98 (Reapproved 2003), Standard Guide for Laboratory Subsampling of Media Related to Waste Management Activities, (Approved August 10, 2003), IBR approved for table 6 to subpart DDDDD and table 5 to subpart JJJJJJ.

(77) ASTM D6348-03, Standard Test Method for Determination of Gaseous Compounds by Extractive Direct Interface Fourier Transform Infrared (FTIR) Spectroscopy, IBR approved for §§63.457(b) and 63.1349, table 4 to subpart DDDD, table 4 to subpart ZZZZ, and table 8 to subpart HHHHHHH.

(78) ASTM D6348-03 (Reapproved 2010), Standard Test Method for Determination of Gaseous Compounds by Extractive Direct Interface Fourier Transform Infrared (FTIR) Spectroscopy, including Annexes A1 through A8, Approved October 1, 2010, IBR approved for §63.1571(a), tables 4 and 5 to subpart JJJJJ, tables 4 and 6 to subpart KKKKK, tables 1, 2, and 5 to subpart UUUUU and appendix B to subpart UUUUU.

(79) ASTM D6348-12e1, Standard Test Method for Determination of Gaseous Compounds by Extractive Direct Interface Fourier Transform Infrared (FTIR) Spectroscopy, Approved February 1, 2012, IBR approved for §63.1571(a).

(80) ASTM D6350-98 (Reapproved 2003), Standard Test Method for Mercury Sampling and Analysis in Natural Gas by Atomic Fluorescence Spectroscopy, (Approved May 10, 2003), IBR approved for table 6 to subpart DDDDD.


(81) ASTM D6357-11, Test Methods for Determination of Trace Elements in Coal, Coke, and Combustion Residues from Coal Utilization Processes by Inductively Coupled Plasma Atomic Emission Spectrometry, (Approved April 1, 2011), IBR approved for table 6 to subpart DDDDD.

(82) ASTM D6376-10, “Standard Test Method for Determination of Trace Metals in Petroleum Coke by Wavelength Dispersive X-Ray Fluorescence Spectroscopy,” Approved July 1, 2010, IBR approved for §63.849(f).

(83) ASTM D6420-99, Standard Test Method for Determination of Gaseous Organic Compounds by Direct Interface Gas Chromatography-Mass Spectrometry, IBR approved for §§63.5799, 63.5850, and Table 4 of Subpart UUUU.

(84) ASTM D6420-99 (Reapproved 2004), Standard Test Method for Determination of Gaseous Organic Compounds by Direct Interface Gas Chromatography-Mass Spectrometry, (Approved October 1, 2004), IBR approved for §§63.457(b), 63.485(g), 60.485a(g), 63.772(a), 63.772(e), 63.1282(a) and (d), 63.2351(b), and 63.2354(b), and table 8 to subpart HHHHHHH.

(85) ASTM D6420-99 (Reapproved 2010), Standard Test Method for Determination of Gaseous Organic Compounds by Direct Interface Gas Chromatography-Mass Spectrometry, Approved October 1, 2010, IBR approved for §63.670(j) and appendix A to this part: Method 325B.

(86) ASTM D6522-00, Standard Test Method for Determination of Nitrogen Oxides, Carbon Monoxide, and Oxygen Concentrations in Emissions from Natural Gas Fired Reciprocating Engines, Combustion Turbines, Boilers, and Process Heaters Using Portable Analyzers, IBR approved for §63.9307(c).

(87) ASTM D6522-00 (Reapproved 2005), Standard Test Method for Determination of Nitrogen Oxides, Carbon Monoxide, and Oxygen Concentrations in Emissions from Natural Gas Fired Reciprocating Engines, Combustion Turbines, Boilers, and Process Heaters Using Portable Analyzers, (Approved October 1, 2005), IBR approved for table 4 to subpart ZZZZ, table 5 to subpart DDDDDD, table 4 to subpart JJJJJJ, and §§63.772(e) and (h)) and 63.1282(d) and (g).

(88) ASTM D6721-01 (Reapproved 2006), Standard Test Method for Determination of Chlorine in Coal by Oxidative Hydrolysis Microcoulometry, (Approved April 1, 2006), IBR approved for table 6 to subpart DDDDD.

(89) ASTM D6722-01 (Reapproved 2006), Standard Test Method for Total Mercury in Coal and Coal Combustion Residues by the Direct Combustion Analysis, (Approved April 1, 2006), IBR approved for Table 6 to subpart DDDDD and Table 5 to subpart JJJJJJ.

(90) ASTM D6735-01 (Reapproved 2009), Standard Test Method for Measurement of Gaseous Chlorides and Fluorides from Mineral Calcining Exhaust Sources—Impinger Method, IBR approved for tables 4 and 5 to subpart JJJJJ and tables 4 and 6 to subpart KKKKK.

(91) ASTM D6751-11b, Standard Specification for Biodiesel Fuel Blend Stock (B100) for Middle Distillate Fuels, (Approved July 15, 2011), IBR approved for §§63.7575 and 63.11237.

(92) ASTM D6784-02 (Reapproved 2008), Standard Test Method for Elemental, Oxidized, Particle-Bound and Total Mercury in Flue Gas Generated from Coal-Fired Stationary Sources (Ontario Hydro Method), (Approved April 1, 2008), IBR approved for §§63.11646(a), 63.11647(a) and (d), tables 1, 2, 5, 11, 12t, and 13 to subpart DDDDD, tables 4 and 5 to subpart JJJJJ, tables 4 and 6 to subpart KKKKK, table 4 to subpart JJJJJJ, table 5 to subpart UUUUU, and appendix A to subpart UUUUU.

(93) ASTM D6883-04, Standard Practice for Manual Sampling of Stationary Coal from Railroad Cars, Barges, Trucks, or Stockpiles, (Approved June 1, 2004), IBR approved for table 6 to subpart DDDDD.

(94) ASTM D7430-11ae1, Standard Practice for Mechanical Sampling of Coal, (Approved October 1, 2011), IBR approved for table 6 to subpart DDDDD.


(95) ASTM D7520-13, Standard Test Method for Determining the Opacity of a Plume in an Outdoor Ambient Atmosphere, approved December 1, 2013. IBR approved for §§63.1510(f), 63.1511(d), 63.1512(a), 63.1517(b) and 63.1625(b).

(96) ASTM E145-94 (Reapproved 2001), Standard Specification for Gravity-Convection and Forced-Ventilation Ovens, IBR approved for appendix A to subpart PPPP.

(97) ASTM E180-93, Standard Practice for Determining the Precision of ASTM Methods for Analysis and Testing of Industrial Chemicals, IBR approved for §63.786(b).

(98) ASTM E260-91, General Practice for Packed Column Gas Chromatography, IBR approved for §§63.750(b) and 63.786(b).

(99) ASTM E260-96, General Practice for Packed Column Gas Chromatography, IBR approved for §§63.750(b) and 63.786(b).

(100) ASTM E515-95 (Reapproved 2000), Standard Test Method for Leaks Using Bubble Emission Techniques, IBR approved for §63.425(i).

(101) ASTM E711-87 (Reapproved 2004), Standard Test Method for Gross Calorific Value of Refuse-Derived Fuel by the Bomb Calorimeter, (Approved August 28, 1987), IBR approved for table 6 to subpart DDDDD and table 5 to subpart JJJJJJ.

(102) ASTM E776-87 (Reapproved 2009), Standard Test Method for Forms of Chlorine in Refuse-Derived Fuel, (Approved July 1, 2009), IBR approved for table 6 to subpart DDDDD.

(103) ASTM E871-82 (Reapproved 2006), Standard Test Method for Moisture Analysis of Particulate Wood Fuels, (Approved November 1, 2006), IBR approved for table 6 to subpart DDDDD and table 5 to subpart JJJJJJ.

(104) ASTM UOP539-12, Refinery Gas Analysis by GC, Copyright 2012 (to UOP), IBR approved for §63.670(j).

(i) Bay Area Air Quality Management District (BAAQMD), 939 Ellis Street, San Francisco, California 94109, http://www.arb.ca.gov/DRDB/BA/CURHTML/ST/st30.pdf.

(1) “BAAQMD Source Test Procedure ST-30—Static Pressure Integrity Test, Underground Storage Tanks,” adopted November 30, 1983, and amended December 21, 1994, IBR approved for §63.11120(a).

(2) [Reserved]

(j) British Standards Institute, 389 Chiswick High Road, London W4 4AL, United Kingdom.

(1) BS EN 1593:1999, Non-destructive Testing: Leak Testing—Bubble Emission Techniques, IBR approved for §63.425(i).

(2) BS EN 14662-4:2005, Ambient air quality standard method for the measurement of benzene concentrations—Part 4: Diffusive sampling followed by thermal desorption and gas chromatography, Published June 27, 2005, IBR approved for appendix A to this part: Method 325A and Method 325B.

(k) California Air Resources Board (CARB), 1001 I Street, P.O. Box 2815, Sacramento, CA 95812-2815, Telephone (916) 327-0900, http://www.arb.ca.gov/.

(1) Method 428, “Determination Of Polychlorinated Dibenzo-P-Dioxin (PCDD), Polychlorinated Dibenzofuran (PCDF), and Polychlorinated Biphenyle Emissions from Stationary Sources,” amended September 12, 1990, IBR approved for §63.849(a)(13) and (14).

(2) Method 429, Determination of Polycyclic Aromatic Hydrocarbon (PAH) Emissions from Stationary Sources, Adopted September 12, 1989, Amended July 28, 1997, IBR approved for §63.1625(b).

(3) California Air Resources Board Vapor Recovery Test Procedure TP-201.1—“Volumetric Efficiency for Phase I Vapor Recovery Systems,” adopted April 12, 1996, and amended February 1, 2001 and October 8, 2003, IBR approved for §63.11120(b).


(4) California Air Resources Board Vapor Recovery Test Procedure TP-201.1E—“Leak Rate and Cracking Pressure of Pressure/Vacuum Vent Valves,” adopted October 8, 2003, IBR approved for §63.11120(a).

(5) California Air Resources Board Vapor Recovery Test Procedure TP-201.3—“Determination of 2-Inch WC Static Pressure Performance of Vapor Recovery Systems of Dispensing Facilities,” adopted April 12, 1996 and amended March 17, 1999, IBR approved for §63.11120(a).

(l) Environmental Protection Agency. Air and Radiation Docket and Information Center, 1200 Pennsylvania Avenue NW., Washington, DC 20460, telephone number (202) 566-1745.

(1) California Regulatory Requirements Applicable to the Air Toxics Program, November 16, 2010, IBR approved for §63.99(a).

(2) New Jersey's Toxic Catastrophe Prevention Act Program, (July 20, 1998), IBR approved for §63.99(a).

(3) Delaware Department of Natural Resources and Environmental Control, Division of Air and Waste Management, Accidental Release Prevention Regulation, sections 1 through 5 and sections 7 through 14, effective January 11, 1999, IBR approved for §63.99(a).

(4) State of Delaware Regulations Governing the Control of Air Pollution (October 2000), IBR approved for §63.99(a).

(5) Massachusetts Department of Environmental Protection regulations at 310 CMR 7.26(10)-(16), Air Pollution Control, effective as of September 5, 2008, corrected March 6, 2009, and 310 CMR 70.00, Environmental Results Program Certification, effective as of December 28, 2007. IBR approved for §63.99(a).

(6)(i) New Hampshire Regulations Applicable to Hazardous Air Pollutants, March, 2003. IBR approved for §63.99(a).

(ii) New Hampshire Regulations Applicable to Hazardous Air Pollutants, September 2006. IBR approved for §63.99(a).

(7) Maine Department of Environmental Protection regulations at Chapter 125, Perchloroethylene Dry Cleaner Regulation, effective as of June 2, 1991, last amended on June 24, 2009. IBR approved for §63.99(a).

(8) California South Coast Air Quality Management District's “Spray Equipment Transfer Efficiency Test Procedure for Equipment User, May 24, 1989,” IBR approved for §§63.11173(e) and 63.11516(d).

(9) California South Coast Air Quality Management District's “Guidelines for Demonstrating Equivalency with District Approved Transfer Efficient Spray Guns, September 26, 2002,” Revision 0, IBR approved for §§63.11173(e) and 63.11516(d).

(10) Rhode Island Department of Environmental Management regulations at Air Pollution Control Regulation No. 36, Control of Emissions from Organic Solvent Cleaning, effective April 8, 1996, last amended October 9, 2008, IBR approved for §63.99(a).

(11) Rhode Island Air Pollution Control, General Definitions Regulation, effective July 19, 2007, last amended October 9, 2008. IBR approved for §63.99(a).

(12) Alaska Statute 42.45.045. Renewable energy grant fund and recommendation program, available at http://www.legis.state.ak.us/basis/folio.asp, IBR approved for §63.6675.

(m) U.S. Environmental Protection Agency, 1200 Pennsylvania Avenue NW., Washington, DC 20460, (202) 272-0167, http://www.epa.gov.

(1) EPA-453/R-01-005, National Emission Standards for Hazardous Air Pollutants (NESHAP) for Integrated Iron and Steel Plants—Background Information for Proposed Standards, Final Report, January 2001, IBR approved for §63.7491(g).


(2) EPA-454/B-08-002, Office of Air Quality Planning and Standards (OAQPS), Quality Assurance Handbook for Air Pollution Measurement Systems, Volume IV: Meteorological Measurements, Version 2.0 (Final), March 24, 2008, IBR approved for §63.658(d) and appendix A to this part: Method 325A.

(3) EPA-454/R-98-015, Office of Air Quality Planning and Standards (OAQPS), Fabric Filter Bag Leak Detection Guidance, September 1997, IBR approved for §§63.548(e), 63.7525(j), 63.8450(e), 63.8600(e), and 63.11224(f).

(4) EPA-454/R-99-005, Office of Air Quality Planning and Standards (OAQPS), Meteorological Monitoring Guidance for Regulatory Modeling Applications, February 2000, IBR approved for appendix A to this part: Method 325A.

(5) EPA-625/3-89-016, Interim Procedures for Estimating Risks Associated with Exposures to Mixtures of Chlorinated Dibenzo-p-Dioxins and -Dibenzofurans (CDDs and CDFs) and 1989 Update, March 1989. IBR approved for §63.1513(d).

(6) SW-846-3020A, Acid Digestion of Aqueous Samples And Extracts For Total Metals For Analysis By GFAA Spectroscopy, Revision 1, July 1992, in EPA Publication No. SW-846, Test Methods for Evaluating Solid Waste, Physical/Chemical Methods, Third Edition, IBR approved for table 6 to subpart DDDDD and table 5 to subpart JJJJJJ.

(7) SW-846-3050B, Acid Digestion of Sediments, Sludges, and Soils, Revision 2, December 1996, in EPA Publication No. SW-846, Test Methods for Evaluating Solid Waste, Physical/Chemical Methods, Third Edition, IBR approved for table 6 to subpart DDDDD and table 5 to subpart JJJJJJ.

(8) SW-846-7470A, Mercury In Liquid Waste (Manual Cold-Vapor Technique), Revision 1, September 1994, in EPA Publication No. SW-846, Test Methods for Evaluating Solid Waste, Physical/Chemical Methods, Third Edition, IBR approved for table 6 to subpart DDDDD and table 5 to subpart JJJJJJ.

(9) SW-846-7471B, Mercury In Solid Or Semisolid Waste (Manual Cold-Vapor Technique), Revision 2, February 2007, in EPA Publication No. SW-846, Test Methods for Evaluating Solid Waste, Physical/Chemical Methods, Third Edition, IBR approved for table 6 to subpart DDDDD and table 5 to subpart JJJJJJ.

(10) SW-846-8015C, Nonhalogenated Organics by Gas Chromatography, Revision 3, February 2007, in EPA Publication No. SW-846, Test Methods for Evaluating Solid Waste, Physical/Chemical Methods, Third Edition, IBR approved for §§63.11960, 63.11980, and table 10 to subpart HHHHHHH.

(11) SW-846-8260B, Volatile Organic Compounds by Gas Chromatography/Mass Spectrometry (GC/MS), Revision 2, December 1996, in EPA Publication No. SW-846, Test Methods for Evaluating Solid Waste, Physical/Chemical Methods, Third Edition, IBR approved for §§63.11960, 63.11980, and table 10 to subpart HHHHHHH.

(12) SW-846-8270D, Semivolatile Organic Compounds by Gas Chromatography/Mass Spectrometry (GC/MS), Revision 4, February 2007, in EPA Publication No. SW-846, Test Methods for Evaluating Solid Waste, Physical/Chemical Methods, Third Edition, IBR approved for §§63.11960, 63.11980, and table 10 to subpart HHHHHHH.

(13) SW-846-8315A, Determination of Carbonyl Compounds by High Performance Liquid Chromatography (HPLC), Revision 1, December 1996, in EPA Publication No. SW-846, Test Methods for Evaluating Solid Waste, Physical/Chemical Methods, Third Edition, IBR approved for §§63.11960 and 63.11980, and table 10 to subpart HHHHHHH.

(14) SW-846-5050, Bomb Preparation Method for Solid Waste, Revision 0, September 1994, in EPA Publication No. SW-846, Test Methods for Evaluating Solid Waste, Physical/Chemical Methods, Third Edition IBR approved for table 6 to subpart DDDDD.

(15) SW-846-6010C, Inductively Coupled Plasma-Atomic Emission Spectrometry, Revision 3, February 2007, in EPA Publication No. SW-846, Test Methods for Evaluating Solid Waste, Physical/Chemical Methods, Third Edition, IBR approved for table 6 to subpart DDDDD.

(16) SW-846-6020A, Inductively Coupled Plasma-Mass Spectrometry, Revision 1, February 2007, in EPA Publication No. SW-846, Test Methods for Evaluating Solid Waste, Physical/Chemical Methods, Third Edition, IBR approved for table 6 to subpart DDDDD.


(17) SW-846-7060A, Arsenic (Atomic Absorption, Furnace Technique), Revision 1, September 1994, in EPA Publication No. SW-846, Test Methods for Evaluating Solid Waste, Physical/Chemical Methods, Third Edition, IBR approved for table 6 to subpart DDDDD.

(18) SW-846-7740, Selenium (Atomic Absorption, Furnace Technique), Revision 0, September 1986, in EPA Publication No. SW-846, Test Methods for Evaluating Solid Waste, Physical/Chemical Methods, Third Edition, IBR approved for table 6 to subpart DDDDD.

(19) SW-846-9056, Determination of Inorganic Anions by Ion Chromatography, Revision 1, February 2007, in EPA Publication No. SW-846, Test Methods for Evaluating Solid Waste, Physical/Chemical Methods, Third Edition, IBR approved for table 6 to subpart DDDDD.

(20) SW-846-9076, Test Method for Total Chlorine in New and Used Petroleum Products by Oxidative Combustion and Microcoulometry, Revision 0, September 1994, in EPA Publication No. SW-846, Test Methods for Evaluating Solid Waste, Physical/Chemical Methods, Third Edition, IBR approved for table 6 to subpart DDDDD.

(21) SW-846-9250, Chloride (Colorimetric, Automated Ferricyanide AAI), Revision 0, September 1986, in EPA Publication No. SW-846, Test Methods for Evaluating Solid Waste, Physical/Chemical Methods, Third Edition, IBR approved for table 6 to subpart DDDDD.

(22) Method 200.8, Determination of Trace Elements in Waters and Wastes by Inductively Coupled Plasma—Mass Spectrometry, Revision 5.4, 1994, IBR approved for table 6 to subpart DDDDD.

(23) Method 1631 Revision E, Mercury in Water by Oxidation, Purge and Trap, and Cold Vapor Atomic Absorption Fluorescence Spectrometry, Revision E, EPA-821-R-02-019, August 2002, IBR approved for table 6 to subpart DDDDD.

(n) International Standards Organization (ISO), 1, ch. de la Voie-Creuse, Case postale 56, CH-1211 Geneva 20, Switzerland, + 41 22 749 01 11, http://www.iso.org/iso/home.htm.

(1) ISO 6978-1:2003(E), Natural Gas—Determination of Mercury—Part 1: Sampling of Mercury by Chemisorption on Iodine, First edition, October 15, 2003, IBR approved for table 6 to subpart DDDDD.

(2) ISO 6978-2:2003(E), Natural gas—Determination of Mercury—Part 2: Sampling of Mercury by Amalgamation on Gold/Platinum Alloy, First edition, October 15, 2003, IBR approved for table 6 to subpart DDDDD.

(3) ISO 16017-2:2003(E): Indoor, ambient and workplace air—sampling and analysis of volatile organic compounds by sorbent tube/thermal desorption/capillary gas chromatography—Part 2: Diffusive sampling, May 15, 2003, IBR approved for appendix A to this part: Method 325A and Method 325B.

(o) National Council of the Paper Industry for Air and Stream Improvement, Inc. (NCASI), P.O. Box 133318, Research Triangle Park, NC 27709-3318 or at http://www.ncasi.org.

(1) NCASI Method DI/MEOH-94.03, Methanol in Process Liquids and Wastewaters by GC/FID, Issued May 2000, IBR approved for §§63.457 and 63.459.

(2) NCASI Method CI/WP-98.01, Chilled Impinger Method For Use At Wood Products Mills to Measure Formaldehyde, Methanol, and Phenol, 1998, Methods Manual, IBR approved for table 4 to subpart DDDD.

(3) NCASI Method DI/HAPS-99.01, Selected HAPs In Condensates by GC/FID, Issued February 2000, IBR approved for §63.459(b).

(4) NCASI Method IM/CAN/WP-99.02, Impinger/Canister Source Sampling Method for Selected HAPs and Other Compounds at Wood Products Facilities, January 2004, Methods Manual, IBR approved for table 4 to subpart DDDD.

(5) NCASI Method ISS/FP A105.01, Impinger Source Sampling Method for Selected Aldehydes, Ketones, and Polar Compounds, December 2005, Methods Manual, IBR approved for table 4 to subpart DDDD.


(p) National Technical Information Service (NTIS), 5285 Port Royal Road, Springfield, VA 22161, (703) 605-6000 or (800) 553-6847; or for purchase from the Superintendent of Documents, U.S. Government Printing Office, Washington, DC 20402, (202) 512-1800.

(1) Handbook 44, Specificiations, Tolerances, and Other Technical Requirements for Weighing and Measuring Devices 1998, IBR approved for §63.1303(e).

(2) “Test Methods for Evaluating Solid Waste, Physical/Chemical Methods,” EPA Publication SW-846, Third Edition. (A suffix of “A” in the method number indicates revision one (the method has been revised once). A suffix of “B” in the method number indicates revision two (the method has been revised twice).

(i) Method 0023A, “Sampling Method for Polychlorinated Dibenzo-p-Dioxins and Polychlorinated Dibenzofuran Emissions from Stationary Sources,” dated December 1996, IBR approved for §63.1208(b).

(ii) Method 9071B, “n-Hexane Extractable Material (HEM) for Sludge, Sediment, and Solid Samples,” dated April 1998, IBR approved for §63.7824(e).

(iii) Method 9095A, “Paint Filter Liquids Test,” dated December 1996, IBR approved for §§63.7700(b) and 63.7765.

(iv) Method 9095B, “Paint Filter Liquids Test,” (revision 2), dated November 2004, IBR approved for the definition of “Free organic liquids” in §§63.10692, 63.10885(a), and the definition of “Free liquids” in §63.10906.

(v) SW-846 74741B, Revision 2, “Mercury in Solid or Semisolid Waste (Manual Cold-Vapor Technique),” February 2007, IBR approved for §63.11647(f).

(3) National Institute of Occupational Safety and Health (NIOSH) test method compendium, “NIOSH Manual of Analytical Methods,” NIOSH publication no. 94-113, Fourth Edition, August 15, 1994.

(i) NIOSH Method 2010, “Amines, Aliphatic,” Issue 2, August 15, 1994, IBR approved for §63.7732(g).

(ii) [Reserved]

(q) North American Electric Reliability Corporation, 1325 G Street, NW., Suite 600, Washington, DC 20005-3801, http://www.nerc.com, http://www.nerc.com/files/EOP0002-3_1.pdf.

(1) North American Electric Reliability Corporation Reliability Standard EOP-002-3, Capacity and Energy Emergencies, adopted August 5, 2010, IBR approved for §63.6640(f).

(2)[Reserved]

(r) Technical Association of the Pulp and Paper Industry (TAPPI), 15 Technology Parkway South, Norcross, GA 30092, (800) 332-8686, http://www.tappi.org.

(1) TAPPI T 266, Determination of Sodium, Calcium, Copper, Iron, and Manganese in Pulp and Paper by Atomic Absorption Spectroscopy (Reaffirmation of T 266 om-02), Draft No. 2, July 2006, IBR approved for table 6 to subpart DDDDD.

(2) [Reserved]

(s) Texas Commission on Environmental Quality (TCEQ) Library, Post Office Box 13087, Austin, Texas 78711-3087, telephone number (512) 239-0028, http://www.tceq.state.tx.us/assets/public/implementation/air/sip/sipdocs/2002-12-HGB/02046sipapp_ado.pdf.

(1) “Air Stripping Method (Modified El Paso Method) for Determination of Volatile Organic Compound Emissions from Water Sources,” Revision Number One, dated January 2003, Sampling Procedures Manual, Appendix P: Cooling Tower Monitoring, January 31, 2003, IBR approved for §§63.654(c) and (g), 63.655(i), and 63.11920.

(2) [Reserved]


§63.15 Availability of information and confidentiality.

(a) Availability of information.

(1) With the exception of information protected through part 2 of this chapter, all reports, records, and other information collected by the Administrator under this part are available to the public. In addition, a copy of each permit application, compliance plan (including the schedule of compliance), notification of compliance status, excess emissions and continuous monitoring systems performance report, and title V permit is available to the public, consistent with protections recognized in section 503(e) of the Act.

(2) The availability to the public of information provided to or otherwise obtained by the Administrator under this part shall be governed by part 2 of this chapter.

(b) Confidentiality.

(1) If an owner or operator is required to submit information entitled to protection from disclosure under section 114(c) of the Act, the owner or operator may submit such information separately. The requirements of section 114(c) shall apply to such information.

(2) The contents of a title V permit shall not be entitled to protection under section 114(c) of the Act; however, information submitted as part of an application for a title V permit may be entitled to protection from disclosure.

§63.16 Performance Track Provisions.

(a) Notwithstanding any other requirements in this part, an affected source at any major source or any area source at a Performance Track member facility, which is subject to regular periodic reporting under any subpart of this part, may submit such periodic reports at an interval that is twice the length of the regular period specified in the applicable subparts; provided, that for sources subject to permits under 40 CFR part 70 or 71 no interval so calculated for any report of the results of any required monitoring may be less frequent than once in every six months.

(b) Notwithstanding any other requirements in this part, the modifications of reporting requirements in paragraph (c) of this section apply to any major source at a Performance Track member facility which is subject to requirements under any of the subparts of this part and which has:

(1) Reduced its total HAP emissions to less than 25 tons per year;

(2) Reduced its emissions of each individual HAP to less than 10 tons per year; and

(3) Reduced emissions of all HAPs covered by each MACT standard to at least the level required for full compliance with the applicable emission standard.

(c) For affected sources at any area source at a Performance Track member facility and which meet the requirements of paragraph (b)(3) of this section, or for affected sources at any major source that meet the requirements of paragraph (b) of this section:

(1) If the emission standard to which the affected source is subject is based on add-on control technology, and the affected source complies by using add-on control technology, then all required reporting elements in the periodic report may be met through an annual certification that the affected source is meeting the emission standard by continuing to use that control technology. The affected source must continue to meet all relevant monitoring and recordkeeping requirements. The compliance certification must meet the requirements delineated in Clean Air Act section 114(a)(3).

(2) If the emission standard to which the affected source is subject is based on add-on control technology, and the affected source complies by using pollution prevention, then all required reporting elements in the periodic report may be met through an annual certification that the affected source is continuing to use pollution prevention to reduce HAP


emissions to levels at or below those required by the applicable emission standard. The affected source must maintain records of all calculations that demonstrate the level of HAP emissions required by the emission standard as well as the level of HAP emissions achieved by the affected source. The affected source must continue to meet all relevant monitoring and recordkeeping requirements. The compliance certification must meet the requirements delineated in Clean Air Act section 114(a)(3).

(3) If the emission standard to which the affected source is subject is based on pollution prevention, and the affected source complies by using pollution prevention and reduces emissions by an additional 50 percent or greater than required by the applicable emission standard, then all required reporting elements in the periodic report may be met through an annual certification that the affected source is continuing to use pollution prevention to reduce HAP emissions by an additional 50 percent or greater than required by the applicable emission standard. The affected source must maintain records of all calculations that demonstrate the level of HAP emissions required by the emission standard as well as the level of HAP emissions achieved by the affected source. The affected source must continue to meet all relevant monitoring and recordkeeping requirements. The compliance certification must meet the requirements delineated in Clean Air Act section 114(a)(3).

(4) Notwithstanding the provisions of paragraphs (c)(1) through (3), of this section, for sources subject to permits under 40 CFR part 70 or 71, the results of any required monitoring and recordkeeping must be reported not less frequently than once in every six months.

Table 1 to Subpart A of Part 63—Detection Sensitivity Levels (grams per hour)

Monitoring frequency per subparta Detection sensitivity level

Bi-Monthly 60

Semi-Quarterly 85

Monthly 100 aWhen this alternative work practice is used to identify leaking equipment, the owner or operator must choose one of the monitoring frequencies listed in this table, in lieu of the monitoring frequency specified in the applicable subpart. Bi-monthly means every other month. Semi-quarterly means twice per quarter. Monthly means once per month.

Technical Support Document, Permit Number: 07100002- 014 Page 1 of 42

Technical Support Document

For Air Emission Permit No. 07100002-014

This technical support document (TSD) is intended for all parties interested in the permit and to meet the requirements that have been set forth by the federal and state regulations (40 CFR § 70.7(a)(5) and Minn. R. 7007.0850, subp. 1). The purpose of this document is to provide the legal and factual justification for each applicable requirement or policy decision considered in the determination to issue the permit. 1. General information

1.1 Applicant and stationary source location Table 1. Applicant and source address

Applicant/Address Stationary source/Address (SIC Code: 2621, 2611)

Boise White Paper, LLC - International Falls 400 2nd Street International Falls, Koochiching County, Minnesota 56649 Air permit contact : Kara Huziak, 218-285-5449

Boise White Paper, LLC - International Falls 400 2nd Street International Falls, Koochiching County, Minnesota 56649

1.2 Facility description

Boise White Paper, LLC operates an integrated Kraft pulp and paper mill in International Falls, Minnesota. The mill manufactures a variety of coated and uncoated fine paper products. The facility consists of a wood yard, chip processing center, pulp mill, bleach plant, chemical recovery system, power plant, wastewater treatment facility, industrial landfill, paper mill, finishing and sheeting, warehouse, and shipping facilities.

1.3 Description of the activities allowed by this permit action This permit action is the reissuance of the Part 70 operating permit. In addition to the reissuance, a major permit amendment was incorporated into the permit to increase the total facility black liquor solids (BLS) production limit from 44,200 to 46,410 tons per month using a 12-month rolling average. Black Liquor Solids Increase As part of the Kraft pulping process, the facility produces black liquor. The black liquor is the material from the pulping process that contains much of the organic material that was originally in the wood and almost all of the inorganic material that was used in the digesting process. The solids in the black liquor are called black liquor solids (BLS). The black liquor is processed in the multi-effect evaporators to remove water, which concentrates the BLS and produces a combustible material. After the evaporation, the black liquor is burned in the recovery furnace to recover the energy from the BLS and to recover the inorganic material for reuse. Since black liquor is produced from the pulping of wood, the fuel is biomass and is a renewable fuel.

The current Air Emission Permit for this facility contains a limit of 44,200 tons/month (using 12-month rolling average) for BLS. This limit is a total facility requirement which was set in a 2008 major amendment (permit 07100002-009). The permit limit is a Title I Condition since emissions which were used in the PSD (Prevention of Significant Deterioration) modeling from the recovery furnace and the smelt dissolving tank were based on this level of production. However, the recovery furnace is capable of accommodating higher BLS burn rates as the design capacity is approximately 3.2 million pounds/day (equivalent to 49,600 tons/month). Performance tests have been conducted at rates of approximately 2.9 million pounds/day (equivalent to 44,200 tons/month). In addition, based on emissions data from continuous emissions monitoring systems (CEMS) and performance testing, the recovery furnace can operate at the proposed BLS


limit while complying with the existing emission limits so the emissions presented in the most recent air dispersion modeling analysis would still be appropriate.

The initial BLS 12-month limit was calculated based on the maximum pulp production rate and a BLS generation rate based on processing aspen in the pulp mill. However, due to product demand requirements and wood procurement issues, the facility has recently processed more softwood and alternate species which both generate more black liquor per ton of pulp produced. In 2015, the BLS production rate exceeded 44,200 tons of BLS during 5 individual months. However, they continue to maintain the BLS rate below the 12-month limit with the 2015 BLS combustion rate at approximately 96% of the 12-month rolling average.

Because the limit is a Title I permit condition, a major permit amendment is required to increase it. However, the following analysis is provided in this permit application to document that the project is not considered a major modification under the Federal Prevention of Significant Deterioration (PSD) rules under 40 CFR 52.21. This project does not affect the amount of pulp produced; rather, it affects the type of wood species that can be processed. Therefore, the only emission sources affected by the increase in BLS are the Recovery Furnace (EQUI 9) and the Smelt Dissolving Tank (EQUI 945).

1.4 Description of notifications and applications included in this action Table 2. Notifications and applications included in this action

Date received Application/Notification type and description 07/28/2014 Part 70 Permit Reissuance (DQ 4883)

10/20/2009 Administrative Amendment to request extension for performance testing due date (tracking ID 2887)

4/11/2011 Administrative Change to request extension for EQUI 9 Recovery Furnace carbon monoxide CEM RATA due date (tracking ID 3445)

11/9/2011 Permit Reopening to revise operating limits on EQUI 13/TREA 15 (Lime Kiln/Scrubber) (tracking ID 3750)

8/24/2012 Notification of Replacement of Controls (tracking ID 4096)

8/11/2015 Permit Reopening - Lime Kiln operational limit increased to 237 tons/day following performance test (tracking ID 5326)

4/21/2016 Major Amendment to increase facility-wide limit on BLS production (tracking ID 5543)

Table 3. Total facility potential to emit summary

PM tpy

PM10 tpy

PM2.5 tpy

SO2 tpy

NOx tpy

CO tpy

VOC tpy

CO2e tpy

Single HAP tpy

All HAPs tpy

TRS tpy

Total facility limited potential emissions

375

315 305 584 1560 3920 703

1.54E6 193 394 75.6

Total facility actual emissions (2015)

82.1 82.1 82.1 27.5 787 1820 169 * * * *

*Not reported in Minnesota emission inventory. Table 4. Title I Emissions Summary for BLS Increase – Actual to Projected Actual Emissions Test


Pollutant

Projected Actual Emissions (tpy)

Baseline Actual Emissions (tpy)

Projected Emissions Increase Prior to Excludables (tpy)

Excludable Emissions (tpy)

Projected Emissions Increase Including Excludables (tpy)

NSR Significant Thresholds for Major Sources (tpy)

NSR Review Required? (Yes/No)

PM 62.03 55.55 6.48 4.39 2.09 25 No PM10 52.51 47.01 5.5 2.32 3.18 15 No PM2.5 52.51 47.01 5.5 2.32 3.18 10 No NOx 347.9 311.25 36.65 21.26 15.39 40 No SO2 0 0 0 0 0 40 No CO 1242.21 1209.92 32.29 .26 32.03 100 No Ozone (VOC) 5.26 4.72 0.54 .27 0.27 40 No Lead .059 .053 0.006 .003 0.003 0.6 No CO2e 657999 605929 52070 22335 29735 75,000 No TRS 3.76 3.32 0.44 .39 0.05 - No

Table 5. Facility classification

Classification Major Synthetic minor/area Minor/Area New Source Review X Part 70 X Part 63 X

1.5 Changes to permit The permit does not authorize any specific modifications other than the major amendment for BLS increase described above, however, the MPCA has a combined operating and construction permitting program under Minnesota Rules Chapter 7007, and under Minn. R. 7007.0800, the MPCA has authority to include additional requirements in a permit. Under that authority, the following changes to the permit are also made through this permit action: · The permit has been updated to reflect current MPCA templates and standard citation formatting. · Completed requirements and the requirements for equipment that has been removed have been

deleted. · Some requirements have been reordered to help with clarity (i.e., similar requirements are grouped). · The operating limits have been revised for the scrubber (TREA 15) that controls the lime kiln (EQUI 13).

This is a rolled-in reopening, air project tracking number 3750, which followed a performance test in 7/2011.

· Centrifugal collector - CE 430 (No Tempo SI ID) was replaced by TREA 10. This is a rolled-in notification, air project tracking number 4096.

· Air project tracking number 3455 is a rolled-in Administrative Amendment that requested a due date extension for the recovery furnace (EQUI 9) CO CEM RATA. This amendment also requested the correction of permit language regarding RATA requirements.

· Air project tracking number 2887 is a rolled-in Administrative Amendment to extend performance test requirements for the smelt dissolving tank (EQUI 945) and the lime kiln (EQUI 13).

· Air project tracking number 5326 is a Permit reopening to increase the lime kiln operational limit to 237 tons/day following performance test.

· Boiler #8 (EU 450) (No Tempo SI ID) was retired from the Facility and removed from the permit. · New groups were added to the permit:


COMG 11 ClO2 Generator COMG 12 Bleach Plant COMG 13 40 CFR pt. 63, subp. DDDDD

COMG 14 40 CFR pt. 63, subp. S COMG 15 40 CFR pt. 63, subp. MM COMG 16 Internal Combustion Engines COMG 19 Three Causticizers, Lime Slaker

· 40 CFR pt. 63, subp. JJJJ General Requirements have been added to the off-machine coater (EQUI 15). · The requirements for SV 220 (No Tempo SI ID) have been moved to COMG 11 ClO2 Generator. Changes

have been made to the monitoring and recordkeeping requirements. · The requirements for SV 240 (No Tempo SI ID) have been moved to COMG 12 Bleach Plant. Changes

have been made to the monitoring and recordkeeping requirements. · Requirements have been added for wet scrubber (TREA 12), wet scrubber (TREA 13), venturi scrubber

(TREA 2), venturi scrubber (TREA 3), and wet scrubber (TREA 15). · Title I Condition: Avoid major modification under 40 CFR 52.21(b)(2) & Minn. R. 7007.3000 citation has

been added to the recovery furnace (EQUI 9) CO limit of < 2289 tons per year. This is the appropriate citation based on a review of the 2008 major amendment, permit action 009.

· MR 903 (no Tempo ID) Lime Kiln TRS CEM has been replaced by EQUI 78. · EQUI 113 (MR 430) Boiler 2 NOx/SO2 CEM has been replaced by EQUI 949. · EQUI 129 (MR 433) Boiler 2 airflow parametric monitor has been replaced by EQUI 948. · MN Standards for Stationary Sources opacity limits have been removed from Boilers #3 (EQUI 17) and #9

(EQUI 18) because they are both subject to 40 CFR pt. 60, subp. Db. · MN Standards for Stationary Sources opacity limits have been removed from the Lime Kiln because it is

subject to 40 CFR pt. 60 subp. BB. · Performance testing for compliance with BACT limits is being added to the permit for the following

units/pollutants: STRU 20/ EQUI 44 Brown Stock Decker SO2, VOC, TRS EQUI 945 Smelt Dissolving Tank VOC EQUI 9 Recovery Furnace SO2, VOC EQUI 940 Intermediate Chip Cyclone PM, PM10

· Performance testing has been added for COMG 7 (Kraft Pulping Process Condensates) to demonstrate compliance with HAPs destruction.

· Requirements and permit limits were moved from STRU 110 to EQUI 945 (Smelt Dissolving Tank) to reflect more accurately where emissions are generated.

· NESHAP DDDDD requirements have been added to EQUI 15, EQUI 16, EQUI 17, and EQUI 18. NESHAP DDDDD requirements are also listed at COMG 13.

· The Operation and Maintenance Plan requirement located at the Total Facility level has been updated from a site-specific requirement to better reflect MPCA standard language.

· The Fugitive Emissions Control Plan has been added to the Appendix, as it is an enforceable part of the permit.

· Non-road engines requirements have been removed from the Total Facility level and a group (COMG 16) has been added to the permit for engines subject to 40 CFR pt. 63, subp. ZZZZ.

· Title V air dispersion modeling requirements for PM10 have been added to the Total Facility section of the permit.

· Modeled parameters for SO2 and NOx have been added to the permit in Appendix I. · PTE (potential to emit) calculations have been updated using various sources for emission factors,

including AP-42, NCASI, permit limits, performance testing results, the 1999 Air Toxics Review, and engineering judgement.


2. Regulatory and/or statutory basis

2.1 New source review (NSR)

The facility is an existing major source under New Source Review regulations. The BLS increase major amendment is not subject to PSD/NSR.

2.2 Part 70 permit program The facility is a major source under the Part 70 permit program.

2.3 New source performance standards (NSPS) The Permittee has stated that the following New Source Performance Standards apply to the operations at this Facility. · 40 CFR pt. 60, subp. BB – Kraft Pulp Mills: recovery furnace (EQUI 9), lime kiln (EQUI 13), smelt dissolving

tank (EQUI 945), brown stock washer and decker (EQUIs 3 and 44), and NCG incineration group (COMG 6)

· 40 CFR pt. 60, subp. Db - Industrial-Commercial-Institutional Steam Generating Units: Boilers #3 (EQUI 17) and #9 (EQUI 18)

Boiler #1 (EQUI 15) and Boiler #2 (EQUI 16) are not subject to 40 CFR pt. 60, subps. D or Db because they were in operation by December, 1956, and December, 1965, respectively, prior to the dates listed in 40 CFR § 60.40 and 40 CFR § 60.40b.

EQUI 941 and EQUI 943, two spark ignition emergency engines that are being added as emission units, are not subject to NSPS Subpart JJJJ because they were in operation prior to all dates listed in 40 CFR § 60.4230.

EQUI 942, a compression ignition emergency engine that is being added as an emission unit, is not subject to NSPS Subpart IIII because it was in operation prior to all dates listed in 40 CFR § 60.4200.

2.4 National emission standards for hazardous air pollutants (NESHAP) The facility is an existing major source of HAPs and is subject to the following NESHAPs:

• 40 CFR pt. 63, subp. S - Pulp & Paper Industry

• 40 CFR pt. 63, subp. MM – Chemical Recovery Combustion Sources at Kraft, Soda, Sulfite, and Stand- alone Semichemical Pulp Mills

• 40 CFR pt. 63, subp. JJJJ - Paper and Other Web Coating

Other NESHAPs being included in the permit as of this reissuance:

• 40 CFR pt. 63, subp. DDDDD - Industrial, Commercial, and Institutional Boilers and Process Heaters (EQUI 15, EQUI 16, EQUI 17, and EQUI 18)

• 40 CFR pt. 63, subp. ZZZZ - Stationary Reciprocating Internal Combustion Engines (EQUI 941, EQUI 942, and EQUI 943)

2.5 Compliance assurance monitoring (CAM)


The table below lists the sources which are subject to CAM, whether the source is a large pollutant specific emission unit (PSEU), and the monitoring for the applicable pollutants. Table 6. CAM summary

Unit Control CAM applicability Pollutant EQUI 9 TREA 1 ESP Large PM/PM10 EQUI 945 TREA 2/3 Venturi

Scrubbers Other PM/PM10

EQUI 13 TREA 15 Venturi Scrubber

Other PM/PM10

EQUI 16 TREA 5 ESP Large PM/PM10 For large pollutant specific emission units, records of the monitored parameter must be made at a minimum of 4 times per hour, or once every 15 minutes. For other PSEUs (not large), records must be made at a minimum of once per 24 hours. See Attachment 4 to this document for the CAM Plan submitted by the applicant. In previous permits, there were pieces of equipment listed as control equipment that are better defined as inherent process equipment as defined in 40 CFR 64.1. Because of this designation, these units/control equipment are not subject to CAM and have been removed from the CAM Plan: • TREA 10 (replacement for CE 430 (No Tempo ID)) Centrifugal Collector – PM/PM10 control for Boiler #2 (EQUI 16) • TREA 20 Flue Gas Recirculation – NOx control for Boiler #3 (EQUI 17) • TREA 4 Centrifugal Collector – PM/PM10 control for Boiler #1 (EQUI 13)

2.6 Minnesota State Rules Portions of the facility are subject to the following Minnesota Standards of Performance: · Minn. R. 7011.0150 Standards for Preventing Particulate Matter from Becoming Airborne · Minn. R. 7011.0510 Standards of Performance for Existing Indirect Heating Equipment · Minn. R. 7011.0610 Standards of Performance for Fossil-Fuel-Burning Direct Heating Equipment · Minn. R. 7011.0715 Standards of Performance for Post-1969 Industrial Process Equipment · Minn. R. 7011.2300 Standards of Performance for Stationary Internal Combustion Engines · Minn. R. 7011.2450 Standards of Performance for New Kraft Pulp Mills · Minn. R. 7011.7385 Emission Standards for Paper and Other Web Coating · Minn. R. 7011.7700 Emission Standards for Pulp and Paper Production · Minn. R. 7011.8150 Emission Standards for Stationary Reciprocating Internal Combustion Engines Table 7. Regulatory overview of facility

Subject item* Applicable regulations Rationale COMG 5 (NOx Cap Group Limits)

Title I Condition: 40 CFR 52.21(o)(1)

Prevention of Significant Deterioration. Cap limit for NOx for combustion units (i.e. boilers and recovery furnace). Total NOx cap includes combustion units as well as the lime kiln and smelt dissolving tank. Limit was set in a previous PSD permit due to visibility concerns for Class I area.

COMG 6 (LVHC NCG Incineration and Venting)

40 CFR pt. 63, subp. S National Emission Standards for Hazardous Air Pollutants from the Pulp and Paper Industry

40 CFR pt. 60, subp. BB Standards of Performance for Kraft Pulp Mills Title I Condition: 40 CFR 52.21(j)

Prevention of Significant Deterioration. Requirements for TRS control and NCG (LVHC) venting.


Subject item* Applicable regulations Rationale COMG 7 (Kraft Pulping Process Condensates)

40 CFR 63, subp. S National Emission Standards for Hazardous Air Pollutants from the Pulp and Paper Industry

COMG 8 (HVLC NCG Incineration and Venting)


40 CFR pt. 60, subp. BB Standards of Performance for Kraft Pulp Mills COMG 11 (ClO2

Generator) Minn. Stat. Section 116.07, subds. 4a & 9; Minn. R. 7007.0800, subps. 1, 2 & 43

State-only limits for Cl and ClO2: established due to risk assessment performed as part of PSD permitting for their 1989 permit, number 102A-89-OT-2.

COMG 12 (Bleach Plant)


COMG 16 – (Internal Combustion Engines)

Minn. R. 7011.2300 Standards of Performance for Stationary Internal Combustion Engines

COMG 19 (Three Caustisizers, Lime Slaker)

Minn. R. 7011.0715 Standards of Performance for Post-1969 Industrial Process Equipment

EQUI 9 (Recovery Furnace)

40 CFR pt. 60, subp. BB Standards of Performance for Kraft Pulp Mills

40 CFR pt. 63, subp. MM

National Emission Standards for Hazardous Air Pollutants from Chemical Recovery Combustion Sources at Kraft, Soda, Sulfite, and Stand-alone Semi-chemical Pulp Mills

Minn. R. 7011.0510 Standards of Performance for Existing Indirect Heating Equipment Determination of applicable limit from rule: · the unit started operation in 1976; · the facility is located outside the cities in Table I; · the unit capacity is greater than 250 MMBtu/hr

Title I Condition: 40 CFR 52.21(j)

Prevention of Significant Deterioration. BACT limits set for PM, PM10, SO2, NOx, CO, VOC, and TRS.

40 CFR pt. 64 This unit is a Large PSEU for particulate controls. EQUI 12 (Paint Spray Booth)

Title I Condition: Avoid major modification under 40 CFR 52.21(b)(2)

Prevention of Significant Deterioration. Operational requirement and limit on annual hours are in place to limit particulate matter emissions.

Minn. R. 7011.0715 Standards of Performance for Post-1969 Industrial Process Equipment Determination of applicable limit from rule: · the unit started operation in 1995

EQUI 13 (Lime Kiln) 40 CFR pt. 60, subp. BB Standards of Performance for Kraft Pulp Mills 40 CFR pt. 63, subp. MM

National Emission Standards for Hazardous Air Pollutants from Chemical Recovery Combustion Sources at Kraft, Soda, Sulfite, and Stand-alone Semichemical Pulp Mills

Title I Condition: 40 CFR 52.21(k), Title I Condition: 40 CFR 52.21(b)2)

Prevention of Significant Deterioration. Modeling and netting limits set for PM, PM10, and SO2.


Prevention of Significant Deterioration. BACT limits set for NOx, CO, VOC, and TRS.

40 CFR pt. 64 This unit is “Other” PSEU for particulate controls. EQUI 15 (Boiler #1) Title I Condition: 40 CFR

52.21(k), Title I Condition: 40 CFR 52.21(b)2)

Prevention of Significant Deterioration. Modeling and netting limits set for PM, PM10, and NOx. The limits were derived from computer dispersion modeling.

40 CFR pt. 63, subp. DDDDD National Emission Standards for Hazardous Air Pollutants from Industrial, Commercial, and Institutional Boilers and Process Heaters


Subject item* Applicable regulations Rationale Minn. R. 7011.0510 Standards of Performance for Existing Indirect Heating

Equipment Determination of applicable limit from rule: · the unit started operation in 1956; · the facility is located outside the cities in Table I; · the unit capacity is greater than 250 MMBtu/hr

EQUI 16 (Boiler #2)


Prevention of Significant Deterioration. BACT limits set for PM, PM10, SO2, NOx, and VOC.

Title I Condition: 40 CFR 52.21(j), Title I Condition: 40 CFR 52.21(k)

Prevention of Significant Deterioration. BACT and modeling limits set for SO2 and CO.


Minn. R. 7011.0510 Standards of Performance for Existing Indirect Heating Equipment Determination of applicable limit from rule: · the unit started operation in 1965; · the facility is located outside the cities in Table I; · the unit capacity is greater than 250 MMBtu/hr

40 CFR pt. 64 This unit is a Large PSEU for particulate controls. EQUI 17 (Boiler #3)


Prevention of Significant Deterioration. BACT and modeling limits set for NOx and CO.


Prevention of Significant Deterioration. BACT limit set for VOC.

40 CFR pt. 60, subp. Db Standards of Performance Industrial-Commercial-Institutional Steam Generating Units Determination of applicable limit from rule: · the unit started operation in 1990; • the unit capacity is greater than 250 MMBtu/h


EQUI 18 (Boiler #9)


Prevention of Significant Deterioration. BACT and modeling limit set for NOx.


Prevention of Significant Deterioration. BACT limits set for CO and VOC.

Title I Condition: 40 CFR 52.21(k)

Prevention of Significant Deterioration. Modeling limit set for CO.

40 CFR pt. 60, subp. Db Standards of Performance for Industrial-Commercial-Institutional Steam Generating Units Determination of applicable limit from rule: · the unit started operation in 1990; • the unit capacity is less than 250 MMBtu/h



Subject item* Applicable regulations Rationale EQUI 19, EQUI 20 (Paper Machines #2 and #3)

Minn. R. 7011.0710

Standards of Performance for Pre-1969 Industrial Process Equipment Determination of applicable limits from rule: · the units started operation in 1910

EQUI 21 (Paper Machine #4)

Minn. R. 7011.0610 Standards of Performance for Fossil-Fuel-Burning Direct Heating Equipment

Title I Condition: 40 CFR 52.21

Fuel Burned: Fuel to be burned is limited to natural gas.


Minn. R. 7011.0715

Standards of Performance for Post-1969 Industrial Process Equipment Determination of applicable limits from rule: • the units started operation in 1986 and 1989

EQUI 24 (Sludge Dryer)

Minn. R. 7011.0715 Standards of Performance for Post-1969 Industrial Process Equipment Determination of applicable limit from rule: · the unit started operation in 2001

EQUI 25 (Off-Machine Coater)

40 CFR pt. 63, subp. JJJJ National Emission Standards for Hazardous Air Pollutants from Paper and Other Web Coating

EQUI 940 (Intermediate Chip Booster Station)


Prevention of Significant Deterioration. BACT limits set for PM and PM10.

EQUI 944 (Wastewater Treatment Plant Cooling Tower)


Prevention of Significant Deterioration. BACT limit set for wastewater throughput.

EQUI 945 (Smelt Dissolving Tank)

Title I Condition: 40 CFR 52.21(k), Title I Condition: 40 CFR 52.21(b)2)

Prevention of Significant Deterioration. Modeling and netting limits set for PM, PM10, and SO2.


Prevention of Significant Deterioration. BACT limits set for VOC and TRS.

40 CFR pt. 60, subp. BB Standards of Performance for Kraft Pulp Mills

40 CFR pt. 63, subp. MM


40 CFR pt. 64 This unit is “Other” PSEU for particulate controls. STRU 20 (Brown Stock Decker)

40 CFR pt. 63, subp. S

National Emission Standards for Hazardous Air Pollutants from the Pulp and Paper Industry

Title I Condition: 40 CFR 52 Prevention of Significant Deterioration. This unit has BACT limits for VOC, SO2, and TRS.

TREA 1 (Electrostatic Precipitator - High Efficiency)

40 CFR 64 CAM Applicability – Large PSEU Control of EQUI 9 Recovery Furnace

TREA 2 (Venturi Scrubber)

40 CFR pt. 60, subp. BB Standards of Performance for Kraft Pulp Mills 40 CFR pt. 63, subp. MM



Subject item* Applicable regulations Rationale 40 CFR 64 CAM Applicability – Large PSEU

Control of EQUI 945 Smelt Dissolving Tank TREA 3 (Venturi Scrubber)



40 CFR 64 CAM Applicability – Large PSEU Control of Smelt Dissolving Tank

TREA 5 (Electrostatic Precipitator - High Efficiency)

40 CFR 64 CAM Applicability – Large PSEU Control of Boiler #2

TREA 12 (Wet Scrubber - High Efficiency)

Minn. R. 7007.0800

State-only limits for Cl and ClO2: established due to risk assessment performed as part of PSD permitting for 1989 permit No. 001






40 CFR 64 CAM Applicability – Large PSEU Control of Lime Kiln

*Location of the requirement in the permit (e.g., EQUI0000000001, STRU0000000002, etc.).

The language 'This is a state-only requirement and is not enforceable by the U.S. Environmental Protection Agency (EPA) Administrator and citizens under the Clean Air Act' refers to permit requirements that are established only under state law and are not established under or required by the federal Clean Air Act. The language is to clarify the distinction between permit conditions that are required by federal law and those that are required only under state law. State law-only requirements are not enforceable by the EPA or by citizens under the federal Clean Air Act, but are fully enforceable by the MPCA and citizens under provisions of state law.

3. Technical information

Black Liquor Solids Increase

PSD Calculations To determine applicability of Federal Prevention of Significant Deterioration (PSD) rules under 40 CFR § 52.21 for this project, one must compare the emissions before the change (baseline emissions) with the emissions after the change (post-modification emissions). The emission calculations are presented in the attachments and a description of the various calculation variables are presented below. Baseline Actual Emissions (BAE) The PSD regulation defines the baseline period as the actual emissions during any consecutive 24-month period within the 10-year period before beginning actual construction or receipt of complete permit application. A single pollutant must use the same 24-month period across emission sources (i.e. all NOx emissions must be from the same 24-month period), but different pollutants can use different 24-month periods (i.e. NOx emissions can use one 24-month period and CO can use a different 24-month period).

The baseline actual emissions (BAE) for each pollutant were determined based upon the annual emissions inventory and greenhouse gas reports as submitted to MPCA for calendar years 2007 – 2015


Projected Actual Emissions (PAE) In general, the projected actual emissions were calculated as follows:

Projected Actual Emissions = Future Production Rate (tons/yr) x Future Emission Factor (lb/ton)

The proposed BLS production limit (46,410 tons BLS/month) was used as the future production rate. The future emission factors are based on the most recent quarterly CEMS data and the most recent performance tests which are representative of future operating conditions. Accommodated Emissions or Demand Growth Exclusion (DGE) This regulation allows the facility to exclude emissions that could have been accommodated during the baseline period. For the purpose of this analysis, Boise has referred to these emissions as "Demand Growth Exclusion" (DGE). The requirements for calculating DGE is provided in 40 CFR /52.21(b)(41)(ii)(c):

“Shall exclude, in calculating any increase in emissions that results from the particular project, that portion of the unit's emissions following the project that an existing unit could have accommodated during the consecutive 24-month period used to establish the baseline actual emissions... and that are also unrelated to the particular project, including any increased utilization due to product demand growth.”

Boise has cited two EPA guidance decisions in the application as a basis for their reasoning to include these accommodated emissions in the analysis.

Based on this guidance, the DGE production rate was initially calculated using the operating rates from the highest operating month from 01/2010 - 12/2015 which was during the 10-year baseline period. This monthly production rate was extrapolated to an annual production rate. However, the annualized maximum monthly production rate exceeded the existing BLS 12-month rolling average limit and that rate could not be "legally accommodated." Therefore, the existing BLS limit was used for the DGE calculations. The DGE calculations use the 2015 emission factors as representative of emissions that could have been accommodated. Determination of Emissions Increases Based on the PSD regulations and the information on MPCA permit application form CH-04a, the emissions increases are calculated as follows: Emissions Increase (tons/yr) = Projected Actual (tons/yr) – Baseline (tons/yr) – Accommodated Emissions (tons/yr) EQUI 945 Smelt Dissolving Tank modeling/netting limit This Title I limit is based on an EPA letter from 2008, which approved PM limits based on the Total Facility BLS limit at the time of the letter. The 7.3 pounds per hour limit for PM and PM10 is based on an emission rate limit of 0.12 lb/ton BLS (at that time). This pound per hour limit shall not be increased or made less stringent even though the facility has increased their BLS production. See Appendix H to the permit for more information. Summary Based on the calculations as provided above, this project is not a major modification under PSD (i.e. emissions increases are less than the PSD threshold). However, the BLS limit is a site-specific Title I permit condition, and changing a Title I permit conditions requires a major permit amendment under Minnesota Rules. The extra recordkeeping and reporting requirements described in 40 CFR 52.21(r)(6) are not required for this project because projected actual emissions, when subtracting excludable emissions, are below 50 percent of the amount that is a “significant emissions increase,” as defined under paragraph 40 CFR 52.21(b)(40).


Performance Testing Previous permit actions have included a rationale of “review of Performance Test historical data indicates further testing not warranted” to explain why performance tests weren’t required for certain subject items and limits. Some of these limits and compliance options are being reevaluated in this reissuance, particularly BACT limits that do not have a clear compliance method. The emission subject items and limits that will have new performance testing requirements are listed below. The performance testing requirements have all been entered as an initial performance test followed by the submittal of a performance test plan.

Table 8. Performance testing for compliance with BACT limits Subject Item Pollutant Limit Basis STRU 20/ EQUI 44 Brown Stock Decker

SO2 < 0.02 lb/ton of air dried unbleached pulp

BACT

VOC < 0.20 lb/ton of air dried unbleached pulp, measured as carbon excluding methane

BACT

TRS < 0.12 lb/ton of air dried unbleached pulp, measured as H2S

BACT

EQUI 945 Smelt Dissolving Tank

VOC < 0.09 lb/ton of BLS, measured as carbon excluding methane

BACT

EQUI 9 Recovery Furnace SO2 < 106.2 lbs/hr BACT VOC < 31.3 lbs/hour, measured as

carbon excluding methane BACT

EQUI 940 Intermediate Chip Cyclone

PM < 3.0 lbs/hr BACT PM10 < 2.9 lbs/hr BACT

EQUI 945 The calculation to show that Smelt Dissolving Tank (EQUI 945) is compliant with the COMG 5 Title I Condition NOx limit relies on “the emission factor determined from the most recent MPCA approved performance test.” It was discovered that the requirements for performance testing had been taken out of the permit in a previous permit action, using a rationale of “review of Performance Test historical data indicates further testing not warranted”, and this item has not been tested since September 2006. The MPCA recognizes that past performance test results may have been low for NOx, but since compliance with the NOx limit is based on performance testing, recurring testing must be completed to ensure results are current and accurate. Performance testing requirements have been entered as an initial performance test followed by the submittal of a performance test plan. These testing requirements will ensure that an accurate NOx emission factor is being used for this calculation.

EQUI 25 Performance testing is not required for Off-Machine Coater (EQUI 25) because of alternate compliance method described in 63.3360(d) and 63.3370(c). The equation to show compliance and calculation method are in Appendix C to the permit. EQUI 13 Performance testing was conducted for the lime kiln (EQUI 13) in July of 2014 for PM and PM10. The results were close to the limits for those pollutants. For example, the test result was above 93% of the limit for PM10. Testing was conducted again in October of 2014 for the same pollutants. This testing was a voluntary follow-up test of the July compliance test. The results of these tests were lower. For example, the PM10 test result was around 66% of the limit. This EQUI has a history of inconsistent test results for PM and PM10. A shorter interval for testing frequency may be considered in the future if test results remain close to the limit, or are inconsistent. The current interval for performance testing is every 36 months.


EQUI 17 and EQUI 18 Boiler #3 (EQUI 17) and Boiler #9 (EQUI 18) are subject to NSPS 40 CFR pt. 60, subp. Db Industrial-Commercial-Institutional Steam Generating Units. Pursuant to 40 CFR 60.44b(a)(1), the NOx limit for boilers that burn natural gas and distillate oil depends on whether the unit is designated as “low heat release rate” or “high heat release rate.” From 60.41b, “Heat release rate means the steam generating unit design heat input capacity (in MW or Btu/hr) divided by the furnace volume (in cubic meters or cubic feet).” The Permittee has indicated that Boiler #3 (EQUI 17) at 83,691 BTU/hr-ft3, and Boiler #9 (EQUI 18) at 83,490 BTU/hr-ft3, are both designated as high heat release rate.

EQUI 13 The Permittee has been given approval by the EPA for alternate monitoring for the scrubber that controls emissions from the lime kiln (EQUI 13). Under 40 CFR pt. 63, subp. MM, the scrubber liquid supply pressure is monitored in lieu of the pressure drop across the wet scrubber. This permission is found in the Federal Register Vol. 70, No. 119, dated Wednesday, June 22, 2005 (also found in an appendix G to the permit, a letter from EPA Region 5).

The production or process throughput limit for EQUI 13 has been increased pursuant to Minn. R. 7011.2025, supb. 3. This allows for the operating rate of a unit to be increased to 110 percent of the tested rate following a performance test in which the results for all pollutants were less than or equal to 80 percent of their applicable emission limit. The previous lime production rate of 198 tons per day has been increased to 237 tons per day, 110 percent of the 215 tons per day rate that the test was conducted at. The NOC letter to Boise, dated August 5, 2015, incorrectly classifies the throughput or production limit as “maximum achievable operating rate,” but it is clear from the letter and email correspondence that both parties understood this to mean the production or throughput limit. The averaging time for the lime kiln production limit is 12 hours vs. the standard 8-hour averaging time found in Minn. R. 7017. This is to coincide with NSPS BB monitoring requirements that indicate that TRS should be calculated on a 12-hour average. MPCA Compliance staff has approved this alternate averaging time.

COMG 5 NOx Calculations

EQUI 13 In an effort to limit the number of inputs into compliance analysis, the NOx calculation for the Lime Kiln (EQUI 13) that is used to show compliance for the NOx limit in COMG 5 is based on the BLS (black liquor solids) production rate vs. the production rate of lime. Lime production is dependent on BLS production, therefore, it is an acceptable and reasonable correlation for determining compliance with the NOx limit. Boise provided the following calculation method to convert to tons/day of NOx.

Lime Kiln NOx emissions (tons/day) = (MM lbs BLS/day * 1,000,000/MM * ton/2000 lbs) * (0.21 lbs/ton of BLS * ton/2000 lbs)

Where: MM= million BLS= black liquor solids

Note that 0.21 lbs/ton of BLS produced is the relationship established during the 2012 performance test. This will vary depending on future performance test results. EQUI 945


See Performance Testing section above for explanation of EQUI 945 Smelt Dissolving Tank NOx performance testing requirements for the purpose of establishing an emission factor for COMG 5 NOx calculations.

COMG 19 Three Caustisizers, Lime Slaker

These four units were associated with SV 327 through permit action -005 and then removed from permit action -006 when a ventless scrubbing condenser was added and SV 327 was removed. There were Title I limits on SV 327 that were removed through public notice on permit action -006. These four units remain at the facility as emission units, so are listed in the permit as a group with Minnesota Standards of Performance for Industrial Process Equipment. Boise claims that, because of the condensing scrubber, there are no air emissions from these units. These units are not expected to emit particulate matter.

Tanks

An effort was made to consolidate all tanks or aboveground storage tanks (ASTs) at the Boise facility that are listed with both the Air Quality program and the MPCA Tanks program. When the tanks were migrated from Delta to Tempo, there were duplicate identification numbers between the Air and Tanks programs for the same tank. The goal was to have one EQUI number for each physical tank at the facility, but it was decided that this would not work for both programs. Several tanks were listed as registered aboveground storage tanks, but were not regulated in the Tanks permit. They do, however, require the Tempo fields associated with an air emission unit. With permission from the Tanks program, these ASTs were deleted from the Tempo master file and assigned an air emission unit EQUI number. Other tanks require the Tempo fields associated with an air emission unit and are also regulated in the Tanks permit. These tanks will have both an air emission unit EQUI as well as a Tanks EQUI for use in their permits. These tanks are identified in the Air permit with two ID numbers in the designation field.

Incorrect Types

The MPCA recognizes that there are several incorrect equipment “Type” designations in the permit database. These designations are not in the permit, do not affect permit conditions, and are only listed in the Tempo facility description. These errors were unintended results of data migration from Delta to Tempo. The MPCA will consider addressing this issue in a future permit action at the request of the Permittee

TREA 1 and TREA 5

Annual inspections for Electrostatic Precipitators have been changed to “at least once every two years, or more frequently if required by the manufacturer” to accommodate Boise’s annual 7-day shutdown changing from a 12-month schedule to a 16-month schedule. Both ESPs are subject to CAM and have continuous monitoring and maintenance.

Pressure drop ranges for scrubber subject to CAM

The requirements in 40 CFR 64.3 (a)(3)(i) – (iv) offer indicator range options for pressure drop. The scrubbers controlling EQUIs 13 and 945 that are subject to CAM have been approved to use a minimum pressure drop and scrubber flow rate as indicators of proper operation instead of an indicator range for pressure drop that would contain a minimum and maximum.

Steam Turbine Project 2015 Boise is in the process of replacing old turbines with a new, more efficient, steam turbine to improve electrical generation efficiency at the plant. Boise completed an air permitting analysis to determine if a permit action


was necessary. They determined that the emissions increases qualified as an insignificant modification and that no permit action was necessary. The MPCA reviewed their analysis and is in agreement. A brief air permitting analysis for the project can be found in Attachment 5.

3.1 Calculations of potential to emit (PTE)

Attachment 1 to this TSD contains a summary of the PTE and calculation spreadsheets, as well as supporting information prepared by the MPCA and the Permittee. There are no emission increases authorized by this permit action. The BLS major amendment authorizes an increase in BLS production, but does not increase limits on emissions.

For most units at the Facility, the Permittee calculates limited potential to emit by using permit limits as the emission factor, then shows compliance with the limits through performance testing or continuous emissions monitoring.

3.2 Dispersion modeling Boise completed NAAQS modeling in 2009 to show compliance with the SO2 NAAQS; PSD modeling in 1997 to show compliance with the NOx NAAQS; and NAAQS modeling in 2002 to show compliance with the PM10 NAAQS. All operating restrictions that were assumed when the modeling was conducted have been incorporated as permit limits in the draft Part 70 Reissuance permit. These include PM10 limits on EQUIs 9, 13, 15, 16, 940, and 945; SO2 limits on EQUIs 9, 13, 16, 945, STRU 20, and COMG 6; and NOx limits on EQUIs 9, 13, 15, 16, 17, 18, 945, and COMG 5. In addition, per MPCA practice, a table of the modeled parameters for SO2 and NOx has been added to the permit as Appendix I. With the 1997 PSD/NAAQS modeling, a preliminary analysis for carbon monoxide (CO) was performed, and results indicated that there was no significant impact for CO and therefore the CO analysis was complete. These CO parameters are not included in Appendix I. Other than the specific operating restrictions mentioned above, the parameters listed in Appendix I of the permit describe the operation of the facility at maximum capacity. In other words, the flow rates listed in Appendix I represent the minimum parameters at the maximum emission rates. The MPCA does not require any specific compliance demonstration with these parameters because they are worse-case conditions. The purpose of listing the parameters in the permit appendix is to provide a benchmark for determining if and when additional modeling is required. SO2 Modeling The SO2 concentrations predicted in the 2009 modeling are shown in Table 8.

Table 9. SO2 Modeling Results Percent of Standard (%)

Averaging Period

NAAQS (µg/m3)

MAAQS (µg/m3)

Total modeled concentration (includes background and nearby sources) (µg/m3)

NAAQS MAAQS

Annual 80 80 4.8 6% 6%

24-hr 365 365 50.3 14% 14%

3-hour 1300 915 662 51% 72%

1-hour 1300 1300 862 66% 66% This permit action does not include modeling requirements for SO2 based on an analysis comparing past total facility SO2 modeling and current emission rates. The 2009 total facility modeling results fell under Tier 1 modeling guidance for all averaging periods. Note that the modeled hourly concentration is compared to


the SO2 standard that was in existence at the time. The standard has since been updated and is more restrictive. Because the updated standard is expressed in different units, a direct comparison is not possible; however, since the facility’s permitted hourly SO2 emissions are significantly lower than those modeled in 2009 (168 lbs/hr allowed in their current permit vs. 510 lbs/hr modeled rates (converted from grams/second) for 1-hour and 3-hour NAAQS), the MPCA is confident that there is little to no danger of a NAAQS violation. NOX Modeling The NOX concentrations predicted in the 1996 modeling are shown in Table 9.

Table 10. NOX Modeling Results Percent of Standard (%) Averaging Period

NAAQS (µg/m3)

MAAQS (µg/m3)


NAAQS MAAQS

Annual 100 100 46 46% 46% This permit action does not include modeling requirements for NOx based on an analysis comparing past total facility NOx modeling and current emission rates. The 2002 total facility modeling results fell under Tier 1 modeling guidance for the annual NAAQS averaging period. Note that 1-hour NOX modeling has not been completed; the standard was newly promulgated since the NOX modeling was last completed. Because the predicted annual concentration is significantly lower than the annual standard, and hourly emissions have remained consistent or decreased for some units (Boiler No. 8 retired), the MPCA is confident that there is little imminent threat of violation of the 1-hour standard. PM10 Modeling The PM10 concentrations predicted in the 2002 modeling are shown in Table 9.

Table 11. PM10 Modeling Results Percent of Standard (%)

Averaging Period

NAAQS (µg/m3)

MAAQS (µg/m3)


NAAQS MAAQS

Annual 50 50 32 64% 64%

24-hr 150 150 121 80%% 80% Because incremental changes not requiring re-modeling have been done over the years, and therefore not all particulate emission sources have been included in a PM10 modeling demonstration, Boise is required to complete facility-wide PM10 modeling as a condition of the permit. For this reason, past PM10 modeled parameters have not been included in Appendix I; results and modeled parameters will be included in the next permit action after modeling is completed. PM2.5 Modeling At this time, Boise is not being asked to perform PM2.5 modeling, primarily due to the lack of reliable PM2.5 emissions data. Boise has provided information from the National Council for Air and Stream Improvement, Inc. (NCASI) describing the research that is being done. This and Boise’s PM10 modeling results will inform future decisions on PM2.5 modeling.


3.3 Monitoring

In accordance with the Clean Air Act, it is the responsibility of the owner or operator of a facility to have sufficient knowledge of the facility to certify that the facility is in compliance with all applicable requirements. For CAM, the Permittee submitted a CAM proposal as required by 40 CFR § 64.3. It can be found in Attachment 4 to this TSD. Further discussion of decisions about CAM can be found in Table 5. In evaluating the monitoring included in the permit, the MPCA considered the following:

· the likelihood of the facility violating the applicable requirements; · whether add-on controls are necessary to meet the emission limits; · the variability of emissions over time; · the type of monitoring, process, maintenance, or control equipment data already available for the

emission unit; · the technical and economic feasibility of possible periodic monitoring methods; and · the kind of monitoring found on similar units elsewhere.

Table 11 summarizes the monitoring requirements. Table 12. Monitoring

Subject Item* Requirement (basis) Monitoring Discussion COMG 5 (NOx Cap Group Limits)

The Permittee shall limit emission of Nitrogen Oxides <= 3.67 tons per day from combustion sources (EQUI 9, EQUI 15, EQUI 16, EQUI 17, and EQUI 18). [Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(o)(1)]

Monitoring: CEMS will be used to measure NOx emissions. Calculate and record daily NOx emissions from combustion sources. The NOx emissions from EQUI 9, EQUI 15, EQUI 16, EQUI 17, and EQUI 18 (recovery furnace, boilers #1, #2, #3, and #9) shall be summed together and compared to the NOx limit for the combustion sources (3.67 tons/day).

The NOx emissions from each SI are to be determined from the NOx CEM for that SI. Any exceedances shall be reported with the CEMS EERs.


Subject Item* Requirement (basis) Monitoring Discussion

The Permittee shall limit emissions of Nitrogen Oxides <= 4.18 tons per day, calculated on a semi-annual basis. This limit is the total NOx cap for the facility, and includes the combustion sources (Boilers #1, #2, #3, #9, and the recovery furnace) (EQUI 9, EQUI 15, EQUI 16, EQUI 17, and EQUI 18, respectively) as well as the lime kiln and smelt dissolving tank (EQUI 13 and EQUI 494). [Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(o)(1)]

Calculate: NOx emissions from the smelt dissolving tank and the lime kiln shall be calculated by multiplying the emission factor determined from performance tests and the applicable production rate. The NOx emissions shall be added to the emissions determined from the CEMS and shall then be compared to the total NOx emission limit for COMG 5.

The total NOx emissions shall be calculated on a semi-annual basis. Any exceedances shall be reported with the CEMS EERs.

COMG 6 (LVHC NCG Incineration and Venting)

Hours <= 30 hours per year of NCG (LVHC) Venting: NCG (LVHC) venting (venting directly to the atmosphere, rather than being oxidized in the lime kiln or Boilers #1 or #2) shall be limited to not more than 30 hours per year on a 12-month rolling sum basis. [Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(j)(BACT)]

Recordkeeping: The length of each NCG (LVHC) vent to the atmosphere is tracked electronically and will be documented in an electronic environmental incident report. Daily records are kept and 12-month rolling sum records are calculated monthly.

Reporting: Annually by January 30th, a report of the previous 12 monthly 12-month rolling sum calculations of NCG (LVHC) venting.



Sulfur Dioxide <= 115 tons per year from Boilers #1 and #2 together, on a 12-month rolling sum basis. TRS Control – Backup and Emergency. NCG oxidation in Boilers #1 and #2, in aggregate, shall be limited to allow emissions of SO2 to no more than 115 tons per year from Boilers #1 and #2 together, on a 12-month rolling sum basis. [Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(j)(BACT)]

Recordkeeping: Record of daily emissions and monthly record of hours during which NCG (LVHC) are oxidized in Boiler #1 or #2 and of venting hours and monthly calculation of SO2 emissions from Boiler #1 and #2 and of 12-month rolling sums, by the 15th of the following month. Boiler #1 SO2 emissions shall be calculated using emission factors and operating data, including hours of NCG (LVHC) oxidation. Boiler #2 SO2 emissions shall be calculated using SO2 CEMS data and boiler operating data, including hours of NCG (LVHC) oxidation.

Reporting: Annually by January 30th, a report of the previous 12 monthly 12-month rolling sum calculations of NCG (LVHC) oxidized in Boiler #1 and #2.

COMG 7 (Kraft Pulping Process Condensates)

The pulping process condensates from associated equipment systems that in total contain: HAPs - Total >= 11.1 pounds per ton of ODP (oven-dried pulp) shall be collected and 93% (or 10.2 pounds per ton of ODP) shall be destroyed. [40 CFR 63.446(c)(3), Minn. R. 7011.7700]

Mixed Liquor Volatile Suspended Solids (MLVSS) shall be monitored to demonstrate continuous compliance with the minimum bio-treatment requirement. Recordkeeping: Records of daily condensate flows and calculations using tested emission factors are kept on the Boise Proficy database.

A performance test was performed over a 14-day period in 2012 to establish a relationship between HAPS collected and destroyed per oven-dried ton of pulp, and to show that the destruction efficiency was over 92%. Performance testing requirements are being added to show compliance. Initial performance test is due be the end of 2018, followed by a performance test frequency of every 60 months.

COMG 11 (ClO2

Generator)

The Permittee shall limit emissions of Chlorine Dioxide <= 2.2 pounds per hour 3-hour average [Minn. R. 7007.0800, subp. 2]

Recordkeeping: record once per shift the wet scrubber (TREA 12) pressure drop

Continuous Parametric monitoring: wet scrubber (TREA 12) liquid flow rate

Based on historical performance test results, additional testing on the generator is not warranted. Recordkeeping and subsequent reporting of the wet scrubber parameters is adequate to show compliance with this limit.

The Permittee shall limit emissions of Chlorine <= 0.17 pounds per hour 3-hour average [Minn. R. 7007.0800, subp. 2]

Recordkeeping: record once per shift the wet scrubber (TREA 12) pressure drop

Continuous Parametric monitoring: wet scrubber (TREA 12) liquid flow rate

Based on historical performance test results, additional testing on the generator is not warranted. Recordkeeping and subsequent reporting of the wet scrubber parameters is adequate to show compliance with this limit.


Subject Item* Requirement (basis) Monitoring Discussion COMG 12 (Bleach Plant)

The Permittee shall limit emissions of HAPs - Total <= 10 parts per million or less than or equal to 0.02 lb per ton of oven-dried pulp or reduce the Total Chlorinated HAP mass entering the control device by 99% or more by weight. In this limit, Total HAPs refers to Total Chlorinated HAPs (not including chloroform) [40 CFR 63.445(c), Minn. R. 7011.7700]

Performance testing: Updated testing requirements from 40 CFR subp. S (63.457(a))

Performance Test: for Total Chlorinated HAPs (not including chloroform) based on the sum of all individual chlorinated HAPs or as chlorine, due by September 7, 2015, and thereafter within 60 months. This initial performance test was performed on July 22, 2015. The next test is due July 22, 2020, as required by 40 CFR 63.457(a)(2).

The Permittee shall limit emissions of Chlorine <= 0.41 pounds per hour 3-hour rolling average. [Minn. R. 7007.0800, subp. 2]

Continuous Parametric monitoring: wet scrubber (TREA 13) effluent pH and liquid flow rate

Based on historical performance test results, additional testing on the bleach plant is not warranted. Continuous monitoring, recordkeeping, and subsequent reporting of the wet scrubber parameters is adequate to show compliance with this limit.

The Permittee shall limit emissions of Chlorine Dioxide <= 1.2 pounds per hour 3-hour average. [Minn. R. 7007.0800, subp. 2]

Continuous Parametric monitoring: wet scrubber (TREA 13) effluent pH and liquid flow rate

Based on historical performance test results, additional testing on the bleach plant is not warranted. Continuous monitoring, recordkeeping, and subsequent reporting of the wet scrubber parameters is adequate to show compliance with this limit.

COMG 16 (Internal Combustion Engines)

The Permittee shall limit emissions of Sulfur Dioxide <= 0.50 pounds per million BTU heat input [Minn. R. 7011.2300, subp. 2(A)]

Recordkeeping: hours of operation and fuel type

These units are emergency engines that are used on a limited basis. The emission factor for diesel fuel is 0.29 lb/MMBtu. Boise uses low-sulfur diesel which will ensure that they remain below the limit of 0.0015 lb/MMBtu, which is effective January 31, 2018.

COMG 19 (Three Causticizers, Lime Slaker)

The Permittee shall limit Particulate Matter <= 0.30 grains per dry standard cubic foot of exhaust gas [Minn. R. 7011.0715]

None These units are controlled by a condensing scrubber. The units in COMG 19 are not expected to emit particulate matter.


Subject Item* Requirement (basis) Monitoring Discussion EQUI 9 (Recovery Furnace)

The Permittee shall limit Process Throughput <= 1595 tons per day of virgin black liquor solids (virgin bone dried basis), calculated on a twelve-hour block average. The Production limit located at the facility level also applies at all times. [Minn. R. 7017.2025, subp. 3]

Recordkeeping: Throughput is measured by the rate of BLS fired in the Recovery Furnace (EQUI 9). The process throughput rate is monitored and recorded continuously by the Boise PI system.

The twelve-hour block average shall be calculated by dividing the total weight by the total operating time in each twelve-hour block. Down time of 15 or more minutes is not to be included as operating time. The Production limit located at the facility level also applies at all times.

The Permittee shall limit emissions of Sulfur Dioxide <= 200 tons per year 12-month rolling sum. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

Performance Testing and record keeping

Performance testing requirements are being added to show compliance with BACT limit. Initial performance test is due 180 days after permit issuance, followed by a performance test frequency plan.

The Permittee shall limit emissions of Sulfur - Total Reduced including H2S <= 5 parts per million 12-hour average, calculated on a dry basis and corrected to 8% oxygen. [40 CFR 60.283(a)(2), Minn. R. 7011.2450, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

Monitoring: CEMS will be used to measure TRS emissions. Recordkeeping

Monitor uptime and excess emissions results reported on quarterly DRF-1. Data collected on CEM Data acquisition system and retained for at least 5 years. CEMS Operation and Maintenance: The Permittee will maintain the TRS CEMS by following Quality Assurance Procedures listed in Minn. R. ch. 7017. The TRS CEM will provide continuous assurance of compliance with the TRS emission limit; therefore no additional monitoring is warranted.

The Permittee shall limit Sulfur Content of Fuel <= 0.05 percent by weight distillate oil sulfur content. [Minn. R. 7007.0800, subp. 2]

Fuel Supplier Documentation: The Permittee shall obtain and maintain fuel supplier documentation for each shipment of fuel distillate oil (#1 and #2), documenting that the sulfur content does not exceed 0.05% by weight. Records shall be maintained for 5 years.

Purchasing keeps vendor records. The potential to emit from the allowable fuel is 0.051 lb/MMBtu.



The Permittee shall limit emissions of Total Particulate Matter <= 27.0 pounds per hour 3-hour average. This is more stringent than the NSPS subp. BB and MACT MM limits of 0.044 gr/dscf @ 8% O2, which also apply. [40 CFR 63.862(a)(1)(ii), Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

Performance testing and record keeping

Performance Test: due before end of each 60 months starting 09/13/2006 to measure Total Particulate Matter emissions. The next test is due September 13, 2021.

The Permittee shall limit Opacity <= 35 percent opacity 3-hour average (NSPS supb. BB limit). [40 CFR 60.282(a)(ii), Minn. R. 7011.2450]

Emissions Monitoring: The Permittee shall use a COMS to measure Opacity emissions from EQUI 9.

COM verifies compliance status.

The Permittee shall limit emissions of PM < 10 micron <= 19.2 pounds per hour 3-hour average. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

Performance testing and record keeping

Performance Test: due before end of each 60 months starting 09/13/2006 to measure PM < 10 microns. The next test is due September 13, 2021. Past performance test results have been less than 60% of the limit.

The Permittee shall limit emissions of Sulfur Dioxide <= 106.2 pounds per hour 3-hour average. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

Performance Testing and record keeping

Performance testing requirements are being added to show compliance with BACT limits. Initial performance test is due 365 days after permit issuance, followed by a performance test frequency plan.

The Permittee shall limit emissions of Nitrogen Oxides <= 110 pounds per hour 30-day rolling average. This is equivalent to 80 ppm on a dry basis, corrected to 8% oxygen. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

Monitoring: CEMS will be used to measure NOx emissions. Recordkeeping

Monitor uptime and excess emissions results reported on quarterly DRF-1. Data collected on CEM Data acquisition system and retained for at least 5 years. CEMS Operation and Maintenance: The Permittee will maintain the NOx CEMS by following Quality Assurance Procedures listed in Minn. R. ch. 7017. The NOx CEM will provide continuous assurance of compliance with the NOx emission limit; therefore no additional monitoring is warranted.



The Permittee shall limit emissions of Carbon Monoxide <= 538 pounds per hour 24-hour rolling average. This is equivalent to 600 ppm on a dry basis, corrected to 8% oxygen. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

Monitoring: CEMS will be used to measure CO emissions. Recordkeeping

Monitor uptime and excess emissions results reported on quarterly DRF-1. Data collected on CEM Data acquisition system and retained for at least 5 years. CEMS Operation and Maintenance: The Permittee will maintain the CO CEMS by following Quality Assurance Procedures listed in Minn. R. ch. 7017. The CO CEM will provide continuous assurance of compliance with the CO emission limit; therefore no additional monitoring is warranted.

The Permittee shall limit emissions of Carbon Monoxide <= 2289 tons per year 12-month rolling average. [Minn. R. 7007.0800, subp. 2]

Monitoring: CEMS will be used to measure CO emissions. Recordkeeping

Monitor uptime and excess emissions results reported on quarterly DRF-1. Data collected on CEM Data acquisition system and retained for at least 5 years. CEMS Operation and Maintenance: The Permittee will maintain the CO CEMS by following Quality Assurance Procedures listed in Minn. R. ch. 7017. The CO CEM will provide continuous assurance of compliance with the CO emission limit; therefore no additional monitoring is warranted.

The Permittee shall limit emissions of Volatile Organic Compounds <= 31.3 pounds per hour 3-hour average measured as Carbon, excluding methane [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

Performance Testing Performance testing requirements are being added to show compliance with BACT limits. Initial performance test is due 60 months after permit issuance, followed by a performance test frequency plan.

The Permittee shall limit Process Throughput <= 30.0 gallons per hour 12-hour average (calculated on a twelve-hour block average) of distillate oil (#1 or #2). [Minn. R. 7007.0800, subps. 4-5, Minn. R. 7007.3000]

Record and calculate every 12 hours the block average of distillate process throughput, in gallons/hour, of distillate oil that was burned in the recovery furnace to verify that the distillate process throughput was less than or equal to 30.0 gallons/ hour. Records shall be maintained for 5 years.

The process throughput rate is monitored and recorded continuously by the Boise PI system.

EQUI 12 (Paint Spray Booth)

Total Particulate Matter <= 0.30 grains per dry standard cubic foot of exhaust gas [Minn. R. 7011.0715, subp. 1(A)]

Operation and Maintenance: replace filter in accordance with Manufacturers guidance

Spray Booth Operation: The particulate filter for the SI shall be securely in place whenever paint spraying occurs. The filter shall be maintained and replaced according to manufacturer's specifications.



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

Maintenance – replace filter in accordance with Manufacturers guidance

Spray Booth Operation: The particulate filter for the emission unit shall be securely in place whenever paint spraying occurs. The filter shall be maintained and replaced according to manufacturer's specifications. Opacity is not an area of concern due to the nature of emissions from a paint spray booth.

Operating Hours <= 1044 hours per year 12-month rolling sum. [Title I Condition: Avoid major modification under 40 CFR 52.21(b)(2) and Minn. R. 7007.3000]

Recordkeeping: Monthly record of operating hours and monthly calculation of 12-month rolling sum, by the 15th of the following month

Reporting: Annually by January 30th, a report of the previous 12 monthly 12-month rolling sum calculations of spray booth operation. Monitoring actual hours of operation will ensure VOC emissions are minimized. Maintaining monthly records under 1044 operating hours will be adequate to ensure VOC emissions will not be exceeded.

EQUI 13 (Lime Kiln)

The Permittee shall limit emissions of Sulfur - Total Reduced including H2S <= 8.0 parts per million 12-hour average, calculated on a dry basis and corrected to 10% oxygen. [40 CFR 60.283(a)(5), Minn. R. 7011.2450, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

CEM and recordkeeping Monitor uptime and excess emissions results reported on quarterly DRF-1. Data collected on CEM Data acquisition system and retained for at least 5 years. CEMS Operation and Maintenance: The Permittee will maintain the TRS CEMS by following Quality Assurance Procedures listed in Minn. R. ch. 7017. The TRS CEM will provide continuous assurance of compliance with the TRS emission limit; therefore no additional monitoring is warranted.

The Permittee shall limit emissions of Total Particulate Matter <= 0.066 grains per dry standard cubic foot 3-hour average @10% oxygen. [40 CFR 60.282(a)(3)(i), 40 CFR 63.862(a)(ii), Minn. R. 7011.2450, Minn. R. 7011.7700]

Performance Testing Performance Test: due before end of each 36 months starting 11/06/2008 to measure Total Particulate Matter. The next test is due November 6, 2017. A performance test from September 2007 resulted in an exceedance of this limit (0.064 gr/dscf at that time). In a follow-up test performed in October 2007, the result was 84% of the limit.

The Permittee shall limit emissions of Nitrogen Oxides <= 34.9 pounds per hour 3-hour average [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(modeling)]

Performance Testing Performance Test: due before end of each 60 months starting 09/05/2007 to measure Nitrogen Oxides emissions. The next test is due September 5, 2017. Past performance, test results have been less than 60% of the limit.



The Permittee shall limit emissions of Carbon Monoxide <= 23.7 pounds per hour 3-hour average [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(modeling)]

Performance Testing Performance Test: due before end of each 60 months starting 09/05/2007 to measure Carbon Monoxide emissions. The next test is due September 5, 2017. Past performance test results have been less than 60% of the limit.

The Permittee shall limit Production <= 237 tons per day of lime, calculated on an eight-hour block average [Minn. R. 7017.2025, subp. 3, Minn. R. 7017.2025, subp. 3a]

The process throughput rate is monitored, calculated and recorded continuously by the Boise PI system. Recordkeeping: records of the CaO (calcium oxide or lime) production rate in tons/day shall be maintained.

Boise follows the NESHAP monitoring and recordkeeping protocol described in 40 CFR section 63.864, reporting deviations and corrective actions.

The Permittee shall limit emissions of Total Particulate Matter <= 12.7 pounds per hour 3-hour average. [Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

Performance Testing Performance Test: due before end of each 36 months starting 11/06/2008 to measure Total Particulate Matter. The next test is due November 6, 2017. A performance test from September 2007 resulted in an exceedance of this limit (10.6 lbs/hr at that time). In a follow-up test performed in October 2007, the result was 73% of the limit.

The Permittee shall limit emissions of PM < 10 micron <= 12.7 pounds per hour 3-hour average. [Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

Performance Testing Performance Test: due before end of each 36 months starting 11/06/2008 to measure PM < 10 micron. The next test is due November 6, 2017. A performance test from September 2007 resulted in an exceedance of this limit (10.6 lbs/hr at that time). In a follow-up test performed in October 2007, the result was 82% of the limit.

The Permittee shall limit emissions of Volatile Organic Compounds <= 11.4 pounds per hour 3-hour average, measured as Carbon excluding methane [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

Performance Testing Performance Test: due before end of each 60 months starting 09/05/2007 to measure Volatile Organic Compounds. The next test is due September 5, 2017. Past performance test results have been less than 60% of the limit.



The Permittee shall limit emissions of Sulfur Dioxide <= 13.5 pounds per hour 3-hour average [Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

Performance Testing Performance Test: due before end of each 60 months starting 09/05/2007 to measure Sulfur Dioxide. The next test is due September 5, 2017. Past performance test results have been less than 60% of the limit.

EQUI 15 (Boiler #1)

The Permittee shall limit emissions of Total Particulate Matter <= 0.60 pounds per million Btu heat input [Minn. R. 7011.0510, subp. 1, Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

None This unit uses natural gas; therefore, the likelihood of violating the emission limit is very small. Design based PTE for each unit, using AP-42, is 0.0075 lb/MMBtu.

The Permittee shall limit emissions of PM < 10 micron <= 0.60 pounds per million Btu heat input 3-hour average. [Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

None This unit uses natural gas; therefore, the likelihood of violating the emission limit is very small. Design based PTE for each unit, using AP-42, is 0.0075 lb/MMBtu.

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

None Testing not warranted for Natural Gas boiler

The Permittee shall limit emissions of Nitrogen Oxides <= 0.20 pounds per million Btu heat input [Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

CEM and recordkeeping Monitor uptime and excess emissions results reported on quarterly DRF-1. Data collected on CEM Data acquisition system and retained for at least 5 years. CEMS Operation and Maintenance: The Permittee will maintain the NOx CEMS by following Quality Assurance Procedures listed in Minn. R. ch. 7017. The NOx CEM will provide continuous assurance of compliance with the NOx emission limit; therefore no additional monitoring is warranted.

EQUI 16 (Boiler #2)

The Permittee shall limit emissions of Total Particulate Matter <= 13.0 pounds per hour 3-hour average [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

Performance Testing Performance Test: due before end of each 60 months starting 08/08/2010 to measure Total Particulate Matter. The next test is due August 8, 2020. Past performance test results have been less than 60% of the limit.



The Permittee shall limit emissions of PM < 10 micron <= 11.7 pounds per hour 3-hour average [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

Performance Testing Performance Test: due before end of each 60 months starting 08/08/2010 to measure PM < 10 micron emissions. The next test is due August 8, 2020. Past performance test results have been less than 60% of the limit.

The Permittee shall limit Opacity <= 10 percent opacity 24-hour block average [40 CFR 63.7500(a)(2), 40 CFR pt. 63, subp. DDDDD(Table 4), Minn. R. 7011.7050]

ESP Monitoring: The COMS for this emission unit shall be used to assess proper operation of this ESP.

Recordkeeping: The owner or operator must retain records of all COMS monitoring data and support information for a period of five years from the date of the monitoring sample, measurement, or report. Records shall be kept at the source.

The Permittee shall limit emissions of Sulfur Dioxide <= 39.5 pounds per hour using 6-hour rolling average. This limit does not apply when NCG is being oxidized in Boiler #2. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(modeling)]

CEM and recordkeeping Monitor uptime and excess emissions results reported on quarterly DRF-1. Data collected on CEM Data acquisition system and retained for at least 5 years. CEMS Operation and Maintenance: The Permittee will maintain the SO2 CEMS by following Quality Assurance Procedures listed in Minn. R. ch. 7017. The SO2 CEM will provide continuous assurance of compliance with the SO2 emission limit; therefore no additional monitoring is warranted.

The Permittee shall limit emissions of Sulfur Dioxide <= 9.4 pounds per hour 12-month rolling average. This limit does not apply when NCG is being oxidized in Boiler #2. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

CEM and recordkeeping Monitor uptime and excess emissions results reported on quarterly DRF-1. Data collected on CEM Data acquisition system and retained for at least 5 years. CEMS Operation and Maintenance: The Permittee will maintain the SO2 CEMS by following Quality Assurance Procedures listed in Minn. R. ch. 7017. The SO2 CEM will provide continuous assurance of compliance with the SO2 emission limit; therefore no additional monitoring is warranted.

The Permittee shall limit emissions of Nitrogen Oxides <= 100.2 pounds per hour 30-day rolling average. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

CEM and recordkeeping Monitor uptime and excess emissions results reported on quarterly DRF-1. Data collected on CEM Data acquisition system and retained for at least 5 years. CEMS Operation and Maintenance: The Permittee will maintain the NOx CEMS by following Quality Assurance Procedures listed in Minn. R. ch. 7017. The NOx CEM will provide continuous assurance of compliance with the NOx emission limit; therefore no additional monitoring is warranted.



The Permittee shall limit emissions of Carbon Monoxide <= 800 pounds per hour [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(modeling)]

CEM and recordkeeping Monitor uptime and excess emissions results reported on quarterly DRF-1. Data collected on CEM Data acquisition system and retained for at least 5 years. CEMS Operation and Maintenance: The Permittee will maintain the CO CEMS by following Quality Assurance Procedures listed in Minn. R. ch. 7017. The CO CEM will provide continuous assurance of compliance with the CO emission limit; therefore no additional monitoring is warranted.

The Permittee shall limit emissions of Carbon Monoxide <= 200 pounds per hour [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(modeling)]

CEM and recordkeeping Monitor uptime and excess emissions results reported on quarterly DRF-1. Data collected on CEM Data acquisition system and retained for at least 5 years Permittee will maintain the CO CEMS by following Quality Assurance Procedures listed in Minn. R. ch. 7017. The CO CEM will provide continuous assurance of compliance with the CO emission limit; therefore no additional monitoring is warranted..

The Permittee shall limit emissions of Carbon Monoxide <= 720 parts per million 30-day rolling average, calculated by volume on a dry basis @ 3% oxygen. [40 CFR 63.7500(a)(1), 40 CFR pt. 63, subp. DDDDD(Table 2), Minn. R. 7011.7050]

CEM and recordkeeping Monitor uptime and excess emissions results reported on quarterly DRF-1. Data collected on CEM Data acquisition system and retained for at least 5 years. Permittee will maintain the CO CEMS by following Quality Assurance Procedures listed in Minn. R. ch. 7017. The CO CEM will provide continuous assurance of compliance with the CO emission limit; therefore no additional monitoring is warranted.

The Permittee shall limit emissions of Volatile Organic Compounds <= 40.2 pounds per hour 3-hour average, measured as C excluding methane. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

Performance Testing Performance Test: due before end of each 60 months starting 08/08/2010 to measure Volatile Organic Compounds emissions. The next test is due August 8, 2020. Past performance test results have been less than 60% of the limit.

The Permittee shall limit emissions of Mercury <= 5.7E-06 pounds per million Btu heat input 3-hour average. [40 CFR 63.7500(a)(1), 40 CFR pt. 63, subp. DDDDD(Table 2), Minn. R. 7011.7050]

Performance Testing NESHAP Performance Testing has shown results less than 75 percent of the limit for 2 consecutive years, therefore, each performance test must be conducted no more than 37 months after the previous performance test.



The Permittee shall limit emissions of Hydrochloric acid <= 0.022 pounds per million Btu heat input 3-hour average. [40 CFR 63.7500(a)(1), 40 CFR pt. 63, subp. DDDDD(Table 2), Minn. R. 7011.7050]


The Permittee shall limit emissions of Front-half Particulate Matter <= 0.037 pounds per million Btu heat input 3-hour average (Filterable PM - NESHAP limit). [40 CFR 63.7500(a)(1), 40 CFR pt. 63, subp. DDDDD(Table 2), Minn. R. 7011.7050]


Fuel Usage <= 27010 tons per month 12-month rolling average. The fuel usage limit is for combined total of bark, wood refuse, paper, and sludge and shall be expressed in units of green tons per month. [Title I Condition: 40 CFR 52.21(o) & Minn. R. 7007.3000]

The process throughput rate is monitored, calculated and recorded continuously by the Boise PI system.

The fuel usage limit is for combined total of bark, wood refuse, paper, and sludge and shall be expressed in units of green tons per month. Bark usage is measured based on steam generation calculations. Primary sludge is measured by weigh belts and secondary sludge.

Fuel Usage <= 5193 tons per month 12-month rolling average (SLUDGE USAGE LIMIT). [Title I Condition: 40 CFR 52.21(o) & Minn. R. 7007.3000]


The sludge limit is limited to pulp and paper mill wastewater generated sludge.

Fuel Usage: less than or equal to 39.7 tons/hour of bark, wood refuse, paper, and sludge calculated on a six-hour block average. [Minn. R. 7017.2025, subp. 3]


This limit is in effect unless a new limit is set pursuant to Minn. R. 7017.2025, subp. 3, based on the most recent MPCA approved performance test where compliance was demonstrated.


Subject Item* Requirement (basis) Monitoring Discussion EQUI 17 (Boiler #3)

The Permittee shall limit emissions of Nitrogen Oxides <= 0.050 pounds per million Btu heat input 30-day rolling average [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

CEM and Recordkeeping Monitor uptime and excess emissions results reported on quarterly DRF-1. Data collected on CEM Data acquisition system and retained for at least 5 years. There is also an NSPS limit of 0.20 lbs/MMBtu, but the BACT/modeling limit is more stringent.

The Permittee shall limit emissions of Carbon Monoxide <= 33.6 pounds per hour 3-hour average [Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

Performance Testing Performance Test: due before end of each 60 months starting 08/08/2010 to measure Carbon Monoxide emissions. The next test is due August 8, 2020. Past performance test results have been less than 60% of the limit.

The Permittee shall limit emissions of Carbon Monoxide <= 0.090 pounds per million Btu heat input 3-hour average [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]


The Permittee shall limit emissions of Volatile Organic Compounds <= 0.0090 pounds per million Btu heat input 3-hour average, measured as Carbon excluding methane [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

Performance Testing Performance Test: due before end of each 60 months starting 08/08/2010 to measure Volatile Organic Compounds emissions. The next test is due August 8, 2020. Past performance test results have been less than 60% of the limit.

EQUI 18 (Boiler #9)

The Permittee shall limit emissions of Nitrogen Oxides <= 0.050 pounds per million Btu heat input 30-day rolling average. [Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(j) and (k)]

CEM and Recordkeeping Monitor uptime and excess emissions results reported on quarterly DRF-1. Data collected on CEM Data acquisition system and retained for at least 5 years. There is also an NSPS limit of 0.20 lbs/MMBtu, but the BACT/modeling limit is more stringent.



The Permittee shall limit emissions of Carbon Monoxide <= 0.090 pounds per million Btu heat input 3-hour average [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]


The Permittee shall limit emissions of Carbon Monoxide <= 33.6 pounds per hour 3-hour average [Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]


The Permittee shall limit emissions of Volatile Organic Compounds <= 0.0090 pounds per million Btu heat input 3-hour average, measured as C excluding methane [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

Performance Testing Performance Test: due before end of each calendar 60 months starting 08/08/2010 to measure Volatile Organic Compounds emissions. The next test is due August 8, 2020. Past performance test results have been less than 60% of the limit.

EQUI 19, EQUI 20 (Paper Machines #2 and #3)

Opacity <= 20 percent opacity except for one six-minute per hour of not more than 60 percent opacity. [Minn. R. 7011.0710, subp. 1(B)]

The Permittee shall perform proper maintenance of the paper machines so as to prevent excessive amounts of particulate matter from being emitted from the associated stack/vents.

Testing of Paper machines by NCASI (National Council for Air and Stream Improvement) has demonstrated that proper maintenance, as specified by the manufacturer, is sufficient to meet the standard.



Testing of Paper machines by NCASI has demonstrated that proper maintenance, as specified by the manufacturer, is sufficient to meet the standard.


Opacity <= 20 percent opacity except for one six-minute period per hour of not more than 60 percent opacity. [Minn. R. 7011.0610, subp. 1(A)(2)]


This unit uses natural gas; therefore, the likelihood of violating the emission limit is very small.



Total Particulate Matter <= 0.30 grains per dry standard cubic foot of exhaust [Minn. R. 7011.0610, subp. 1(A)(1)]


This unit uses natural gas; therefore, the likelihood of violating the emission limit is very small.








EQUI 24 (Sludge Dryer)


None This unit uses steam generated at another piece of equipment; therefore, the likelihood of violating the emission limit is very small.


Historical Performance Testing

Most recent testing in April 2006. The Permittee shall operate and maintain the control equipment (TREA 25 and TREA 26) at all times that stack gas from the control equipment is vented directly to the atmosphere.

TREA 25 (this requirement applies when the facility is not burning stack gas in Boilers #1 or #2): Liquid Flow Rate >= 70 gallons per minute 3-hour block average. [Minn. R. 7017.2025, subp. 3]

Monitoring, Historical Performance Testing

The Permittee shall operate and maintain the control equipment (TREA 25 and TREA 26) at all times that stack gas from the control equipment is vented directly to the atmosphere. Monitoring and recording information stored in Pi, a data acquisition system.

TREA 25 (this requirement applies when the facility is not burning stack gas in Boilers #1 or #2): Pressure Drop >= 2.0 inches of water column 3-hour block average [Minn. R. 7017.2025, subp. 3]





TREA 26 (this requirement applies when the facility is not burning stack gas in Boilers #1 or #2): Liquid Flow Rate >= 788 gallons per minute 3-hour block average [Minn. R. 7017.2025, subp. 3]



TREA 26 (this requirement applies when the facility is not burning stack gas in Boilers #1 or #2): Pressure Drop >= 0.5 inches of water column 3-hour block average [Minn. R. 7017.2025, subp. 3]



EQUI 25 (Off-Machine Coater)

HAPs - Organic <= 20 percent of the mass of coating solids applied for each calendar month for the web coating line (as defined in 40 CFR Section 63.3310). [40 CFR 63.3320(b)(3), Minn. R. 7011.7385]

Recordkeeping , calculations using Equation 5 explained in Permit Appendix C

Compliance Status Report: due 30 days after end of each calendar half-year following Permit Issuance By the end of each calendar month, the Permittee shall calculate the following for the previous calendar month: 1) The total organic HAP emitted by summing the HAP emissions calculated for all units subject to 40 CFR pt. 63, subp. JJJJ as detailed earlier in this permit; 2) The coating solids content of each coating material applied during the month following the procedure detailed earlier in this permit; and 3) The total organic HAP emission rate based on coating solids applied using Equation 5 of Appendix C of this permit.

Compliance with the recordkeeping and calculations will be adequate to demonstrate compliance with the NESHAP limit.


Subject Item* Requirement (basis) Monitoring Discussion EQUI 940 (Intermediate Chip Booster Station)

Total Particulate Matter <= 3.0 pounds per hour 3-hour average. [40 CFR 52.21(j), Minn. R. 7007.3000]

Performance testing, Periodic Monitoring of control equipment

Performance testing requirements are being added to show compliance with BACT limits. Initial performance test is due 84 months after permit issuance, followed by a performance test frequency plan.

Periodic Monitoring: the Permittee shall perform proper maintenance of the cyclone so as to prevent excessive amounts of particulate matter from being emitted from the associated stack/vents.

PM < 10 micron <= 2.9 pounds per hour 3-hour average. [40 CFR 52.21(j), Minn. R. 7007.3000]

Performance testing, Periodic Monitoring of control equipment

Performance testing requirements are being added to show compliance with BACT limits. Initial performance test is due 84 months after permit issuance, followed by a performance test frequency plan.

Periodic Monitoring: the Permittee shall perform proper maintenance of the cyclone so as to prevent excessive amounts of particulate matter from being emitted from the associated stack/vents.

EQUI 944 (Wastewater Treatment Plant Cooling Tower)

Wastewater: Process Throughput <= 1700 million gallons per year 12-month rolling sum. [Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(j)(BACT)]

Recordkeeping: Monthly wastewater processed rate and monthly calculation of 12-month rolling sum, by the 15th of the following month

Reporting: Annually by January 30th, a report of the previous 12 monthly 12-month rolling sum calculations of wastewater throughput. The process throughput rate is monitored, calculated and recorded continuously by the Boise PI system.

EQUI 945 (Smelt Dissolving Tank)

The Permittee shall limit emissions of Nitrogen Oxides <= 0.033 pounds per ton of BLS (black liquor solids) produced. [Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(o)]

Performance testing used to determine emission factor that is used for the calculations for the COMG 5 NOx limit.

Initial performance test is due 365 days after permit issuance, followed by a performance test frequency plan.

This requirement had been taken out in a previous permit action, however, since the COMG 5 NOx cap (includes EQUI 945) relies on current emission factors or CEMS, this unit needs to be tested at least every 60 months to determine an accurate NOx emission factor.

The Permittee shall limit emissions of Sulfur - Total Reduced including H2S <= 0.033 pounds per ton of BLS (black liquor solids) measured as H2S [40 CFR 60.283(a)(4), Minn. R. 7011.2450, Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

Performance testing on a 60-month frequency based on historical test frequency results

Performance Test: due before end of each 60 months starting 09/12/2006 to measure Total Reduced Sulfur emissions. The next test is due September 12, 2021.



The Permittee shall limit emissions of Total Particulate Matter <= 7.3 pounds per hour 3-hour average. This limit is based on an EPA approved emission limit of 0.12 lb/ton BLS (dry) and thus is more stringent than the NSPS BB and NESHAP MM limit of 0.20 lb/ton BLS for a smelt dissolving tank. [40 CFR 63.862(a)(1)(i)(B), Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

Performance testing on a 60-month frequency based on historical test frequency results.

Limit approved by the EPA in a Letter dated September 29, 2008. Performance Test: due before end of each 60 months starting 09/12/2006 to measure Total Particulate Matter emissions. The next test is due September 12, 2021.

The Permittee shall limit emissions of PM < 10 micron <= 7.3 pounds per hour 3-hour average. [40 CFR 63.862(a)(1)(i)(B), Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

Performance testing on a 60-month frequency based on historical test frequency results.

Limit based on EPA letter dated September 29, 2008. Performance Test: due before end of each 60 months starting 09/12/2006 to measure PM < 10 micron. The next test is due September 12, 2021.

The Permittee shall limit Opacity <= 20 percent opacity 6-minute average. [Minn. R. 7007.0800, subp. 2]

Performance testing MPCA review of Performance Test historical data indicates further testing not warranted in order to meet emission limits due to historical low results.

The Permittee shall limit emissions of Sulfur Dioxide <= 4.3 pounds per hour 3-hour average [Title I Condition: 40 CFR 52.21(k)(modeling) & Minn. R. 7007.3000]

Historical test data used for emission factor.

MPCA review of Performance Test historical data indicates further testing not warranted in order to meet emission limits due to historical low results.

The Permittee shall limit emissions of Volatile Organic Compounds <= 0.090 pounds per ton of BLS (black liquor solids) measured as C excluding methane [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]

Performance Testing Performance testing requirements are being added to show compliance with BACT limits. Initial performance test is due 365 days after permit issuance, followed by a performance test frequency plan.


Subject Item* Requirement (basis) Monitoring Discussion STRU 20 (Brown Stock Decker)

The Permittee shall limit emissions of HAPs - Total <= 400 parts per million by weight (process water). For purposes of complying with the Kraft pulping condensate requirements in 40 CFR Section 63.446, the permittee chooses to measure the total HAP concentration as methanol (see 40 CFR Section 63.457(f)(2)). [40 CFR 63.443(a)(1)(iv)(B), Minn. R. 7011.7700]

Historical Performance Test Performance testing conducted in December 2014, showed the HAPs content of the process water to be 270 ppm by weight.

The Permittee shall limit emissions of Sulfur Dioxide <= 0.020 pounds per ton of air-dried unbleached pulp. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]


The Permittee shall limit emissions of Volatile Organic Compounds <= 0.20 pounds per ton of air-dried unbleached pulp, measured as carbon excluding methane. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]


The Permittee shall limit emissions of Sulfur - Total Reduced including H2S <= 0.12 pounds per ton of air-dried unbleached pulp, measured as H2S. [Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000]



Subject Item* Requirement (basis) Monitoring Discussion TFAC 5 (Total Facility)

The Permittee shall limit emissions of Black Liquor Solids (virgin bone dried basis) Production <= 46410 tons per month 12-month rolling average. [Minn. R. 7007.3000, Title I Condition: 40 CFR 52.21(k)(Modeling)]

Recordkeeping: Monthly record and monthly calculation of 12-month rolling average of the black liquor solids production, by the 15th of the following month.

Records of BLS burned are kept in Proficy database. Liquor shipped offsite (if any) is added into the monthly number and records are kept on the Proficy database. Reporting: Annually by January 30th, a report of the previous 12 monthly 12-month rolling average calculations of the black liquor solids (virgin bone dried basis) production. The additional recordkeeping for BLS Increase project (from permit number 07100002-009, previous limit of 44,200 tons/month) can cease at the end of the 2016 calendar year. There is no additional recordkeeping associated with the Major amendment rolled into this reissuance.

TREA 1 (Electrostatic Precipitator for Recovery Furnace)

Opacity <= 13 percent opacity 3-hour block average. [40 CFR 64.3, Minn. R. 7017.0200]

Emissions Monitoring: The Permittee shall use a COMS to measure Opacity Emissions.

This limit is in place for the purpose of complying with CAM. Boise has stated that there is a correlation between PM and opacity, which can be continuously monitored with a COM. Opacity in excess of this limit shall be considered an excursion under 40 CFR Section 64.6(c)(2).

TREA 2 (Wet scrubber for Smelt dissolving tank)

Pressure Drop >= 10 inches of water column 3-hour block average or as determined during the most recent performance test. [40 CFR 64.3(a), Minn. R. 7017.2025, subp. 3]

Parametric monitoring, daily inspections, recordkeeping, corrective actions and reporting

Pressure drop is monitored continuously and measurements are recorded once per shift to ensure that the scrubber is working properly. The monitoring, recordkeeping, and reporting associated with wet scrubber provide a reasonable assurance that the applicable limit will be met on a continuous basis.

Water Flow Rate >= 81 gallons per minute 3-hour block average or as determined during the most recent performance test. [40 CFR 64.3(a), Minn. R. 7017.2025, subp. 3]

Parametric monitoring and Recordkeeping

Liquid Flow Rate is monitored continuously and measurements are recorded once per shift to ensure that the scrubber is working properly.

TREA 3 (Wet scrubber for Smelt dissolving tank)

Pressure Drop >= 10 inches of water column 3-hour block average or as determined during the most recent performance test. [40 CFR 64.3(a), Minn. R. 7017.2025, subp. 3]


Pressure drop is monitored continuously and measurements are recorded once per shift to ensure that the scrubber is working properly.



Water Flow Rate >= 81 gallons per minute 3-hour block average or as determined during the most recent performance test. [40 CFR 64.3(a), Minn. R. 7017.2025, subp. 3]


Liquid Flow Rate is monitored continuously and measurements are recorded once per shift to ensure that the scrubber is working properly.

TREA 5 (Electrostatic Precipitator for Boiler #2)

Opacity <= 8.5 percent opacity 3-hour block average. [40 CFR 64.3, Minn. R. 7017.0200]

Emissions Monitoring: The Permittee shall use a COMS to measure Opacity Emissions.

This limit is in place for the purpose of complying with CAM. Boise has stated that there is a correlation between PM and opacity, which can be continuously monitored with a COM. Opacity in excess of this limit shall be considered an excursion under 40 CFR Section 64.6(c)(2).

TREA 12 (Scrubber for CLO2 generator)

Pressure Drop >= 3.2 inches of water column 3-hour block average or as determined during the most recent performance test (this is pressure drop of the gas stream). [Minn. R. 7007.0800, subp. 14]


Pressure drop is monitored continuously and measurements are recorded once per shift to ensure that the scrubber is working properly.

Liquid Flow Rate >= 95.7 gallons per minute 3-hour block average or as determined during the most recent performance test (this is scrubbing liquid supply flow rate). [Minn. R. 7007.0800, subp. 14]


Liquid Flow Rate is monitored continuously and maintained to ensure that the scrubber is working properly.

TREA 13 (Scrubber for Bleach plant)

pH >= 11.4 (no units) 3-hour average of the gas scrubber (TREA 13) effluent. [40 CFR 63.453(c)&(n)), Minn. R. 7007.0800, subp. 14, Minn. R. 7011.7700]


pH is monitored continuously and records are kept for corrective actions, etc.

Liquid Flow Rate >= 121 gallons per minute 3-hour block average or as determined during the most recent performance test (this is gas scrubber liquid influent flow rate for TREA 13). [40 CFR 63.453(c)&(n)), Minn. R. 7007.0800, subp. 14, Minn. R. 7011.7700]


Liquid influent flow rate is monitored continuously and records are kept for corrective actions, etc.


Subject Item* Requirement (basis) Monitoring Discussion TREA 15 (Wet Scrubber for Lime Kiln)

Liquid Flow Rate >= 403 gallons per minute 3-hour block average or as determined during the most recent performance test. [40 CFR 63.864(j)(2)&(3), 40 CFR 64.3(a), Minn. R. 7017.2025, subp. 3]


Liquid Flow Rate is monitored continuously and measurements are recorded every 15 minutes to ensure that the scrubber is working properly.

Pressure at Nozzle >= 302 psi using 3-hour block average or as determined during the most recent performance test. [40 CFR 63.864(j)(2)&(3), 40 CFR 64.3(a), Minn. R. 7017.2025, subp. 3]


Pressure drop is monitored continuously and measurements are recorded every 15 minutes to ensure that the scrubber is working properly.

*Location of the requirement in the permit (e.g., EQUI 1, STRU 2, etc.).

3.4 Insignificant activities Boise White Paper LLC - Intl Falls has several operations which are classified as insignificant activities under the MPCA’s permitting rules. These are listed in Appendix A to the permit. The permit is required to include periodic monitoring for all emissions units, including insignificant activities, per EPA guidance. The insignificant activities at this Facility are only subject to general applicable requirements. Using the criteria outlined earlier in this TSD, the following table documents the justification why no additional periodic monitoring is necessary for the current insignificant activities. See Attachment 1 of this TSD for PTE information for the insignificant activities. Table 13. Insignificant activities

Insignificant activity General applicable emission limit Discussion

Fuel Use: space heaters fueled by kerosene, natural gas, or propane, less than 420,000 Btu/hr [Miscellaneous heating units]

PM <= 0.60 or 0.40 lb/MMBtu, depending on year constructed Opacity <= 20% with exceptions (Minn. R. 7011.0510/0515)

For natural gas units, based on the fuels used and EPA published emissions factors, it is highly unlikely that they could violate the applicable requirement.

Infrared electric ovens [Lead dryer]

Opacity <= 20% (Minn. R. 7011.0105 or 7011.0110)

These units are not likely to have any emissions of particulate matter at this site. It is highly unlikely that they could violate the applicable requirement.

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

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

These are small labs, testing areas, etc.; it is highly unlikely that they could violate the applicable requirement.


Insignificant activity General applicable emission limit Discussion

Brazing, soldering or welding equipment [Various welding areas]

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

For these units, based on EPA published emissions factors, it is highly unlikely that they could violate the applicable requirement. In addition, these units are typically operated and vented inside a building, so testing for PM or opacity is not feasible.

Blueprint copiers and photographic processes [Blueprint Machine 1, Blueprint Machine 2]

Opacity <= 20% (Minn. R. 7011.0105 or 7011.0110)

There is the potential for emissions from solvents, toners, etc.; these machines are typically operated and vented inside a building, making testing not feasible.

Individual units with potential emissions less than 2000 lb/year of certain pollutants [Fugitive sources listed in previous permits that qualify as insignificant activities]

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

Calculations have been provided to show that these units/activities are insignificant under Minn. R. 7007.1300, subp. 3(I).

Individual units with potential or actual emissions meeting the criteria in Minn. R. 7007.1300, subp. 4(A)-(D) [Various activities allowed as insignificant because they have been listed since permit action 001]

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

3.5 Permit organization

In general, the permit meets the MPCA Tempo Guidance for ordering and grouping of requirements. One area where this permit deviates slightly from Tempo guidance is in the use of appendices. While appendices are fully enforceable parts of the permit, in general, any requirement that the MPCA thinks should be electronically tracked (e.g., limits, submittals, etc.), should be in the Requirements table in Tempo. The main reason is that the appendices are word processing sections and are not part of the electronic tracking system. Violation of the appendices can be enforced, but the computer system will not automatically generate the necessary enforcement notices or documents. Staff must generate these. For instance, this permit uses an appendix for specific calculation procedures from 40 CFR pt. 63, subp. JJJJ. These procedures are too complex to enter into Tempo and must go in an appendix.

3.6 Comments received The MPCA plans to issue this draft permit under the provisions of Minn. R. 7007.0750, subp. 7. This rule allows the MPCA to issue permits in two stages. The EPA was notified of the MPCA’s intent to issue this permit in two stages on April 13, 2017. The requirements issued in the first stage - the Stage 1 conditions - are the portions of the draft permit at the Total Facility level that relate to the black liquor solids increase and associated recordkeeping authorized by the draft permit. Stage 1 conditions are denoted in the permit by “[Stage 1].” Public Notice Period: April 16, 2017 - May 15, 2017 EPA Review Period: May 17, 2017 - June 1 , 2017


Comments were not received from the public during the public notice period. The revised permit was sent to EPA for their 15-day shortened review on 5/17/2017. Comments were not received from EPA during their review period.

4. Permit fee assessment

This permit action is the reissuance of an individual Part 70; therefore, no application fees apply under Minn. R. 7002.0016, subp. 1 to the changes that are covered by the reissuance application. However, the permit action rolls in three additional permit applications to which fees do apply. Attachment 6 to this TSD contains the MPCA’s assessment of Application and Additional Points used to determine the additional permit application fee as required by Minn. R. 7002.0019. The rolled in permit applications were all received after the effective date of the rule (July 1, 2009), and the application fees were paid at the time of application, so only the additional fees would apply. There are no additional fees associated with the two administrative amendments. There is an additional fee assessed for the major amendment, for a limit to remain under a threshold (an existing limit was increased, the increase limited to below that which would trigger New Source Review).

5. Conclusion Based on the information provided by Boise White Paper LLC - Intl Falls the MPCA has reasonable assurance that the proposed operation of the emission facility, as described in the Air Emission Permit No. 07100002-014 and this TSD, will not cause or contribute to a violation of applicable federal regulations and Minnesota Rules. Staff members on permit team: Brady Krueger (permit engineer)

Amrill Okonkwo (peer reviewer) Steven Palzkill (compliance and enforcement) Andy Place (compliance and enforcement) Lad Strzok (STAMP) Beckie Olson (permit writing assistant) Laurie O’Brien (administrative support)

TEMPO360 Activities: Administrative Change, Applicability Request, Notification of Replacement of Controls, Part 70 Permit Reissuance, Permit Reopening

Attachments: 1. PTE summary and calculation spreadsheets

2. BLS Limit Increase - PSD Permit Applicability Calculations 3. Subject item inventory and facility requirements 4. CAM Plan 5. Steam Turbine Project Air Permitting Analysis 6. Application and Additional Points

Attachment 1: PTE Summary and Calculation Spreadsheets

Boise White Paper LLC - Intl Falls 07100002-014

Boise White Paper, LLC ‐ International Falls, MNPTE Calculations ‐ Point Sources7/22/2014

Stack Emission Unit Throughput Material Units Throughput Material Units EmissionID ID Description Pollutant Type Factor

(lb/Unit) Note Yes/No % (lb/hr) (tons/yr) (lb/hr) (tons/yr)STRU 20 EQUI 44 Brown Stock Decker 1,1,2‐Trichloroethane HAP 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 2.20E‐04 lb/ADTUBP [034] No 0% 1.38E‐02 0.06 1.38E‐02 0.06

STRU 20 EQUI 44 Brown Stock Decker 1,2,4‐Trichlorobenzene HAP 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 2.18E‐03 lb/ADTUBP [034] No 0% 1.36E‐01 0.60 1.36E‐01 0.60

STRU 20 EQUI 44 Brown Stock Decker 1,2‐Dichloroethane HAP 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 1.20E‐06 lb/ADTUBP [034] No 0% 7.50E‐05 0.00 7.50E‐05 0.00

STRU 20 EQUI 44 Brown Stock Decker Acetaldehyde HAP 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 1.09E‐03 lb/ADTUBP [034] No 0% 6.81E‐02 0.30 6.81E‐02 0.30

STRU 20 EQUI 44 Brown Stock Decker Acrolein HAP 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 2.35E‐04 lb/ADTUBP [034] No 0% 1.47E‐02 0.06 1.47E‐02 0.06

STRU 20 EQUI 44 Brown Stock Decker Benzene HAP 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 2.40E‐05 lb/ADTUBP [034] No 0% 1.50E‐03 0.01 1.50E‐03 0.01

STRU 20 EQUI 44 Brown Stock Decker Biphenyl HAP 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 5.80E‐06 lb/ADTUBP [034] No 0% 3.63E‐04 0.00 3.63E‐04 0.00

STRU 20 EQUI 44 Brown Stock Decker Carbon Disulfide HAP 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 8.40E‐05 lb/ADTUBP [034] No 0% 5.25E‐03 0.02 5.25E‐03 0.02

STRU 20 EQUI 44 Brown Stock Decker Carbon Tetrachloride HAP 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 1.20E‐03 lb/ADTUBP [034] No 0% 7.50E‐02 0.33 7.50E‐02 0.33

STRU 20 EQUI 44 Brown Stock Decker Chlorobenzene HAP 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 3.30E‐05 lb/ADTUBP [034] No 0% 2.06E‐03 0.01 2.06E‐03 0.01

STRU 20 EQUI 44 Brown Stock Decker Chloroform HAP 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 3.60E‐05 lb/ADTUBP [034] No 0% 2.25E‐03 0.01 2.25E‐03 0.01

STRU 20 EQUI 44 Brown Stock Decker Cresols (mixed isomers)

HAP 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 1.79E‐02 lb/ADTUBP [034] No 0% 1.12E+00 4.89 1.12E+00 4.89

STRU 20 EQUI 44 Brown Stock Decker Formaldehyde HAP 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 1.40E‐04 lb/ADTUBP [034] No 0% 8.75E‐03 0.04 8.75E‐03 0.04

STRU 20 EQUI 44 Brown Stock Decker m,p‐Cresol HAP 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 8.93E‐03 lb/ADTUBP [034] No 0% 5.58E‐01 2.44 5.58E‐01 2.44

STRU 20 EQUI 44 Brown Stock Decker m,p‐Xylene HAP 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 1.64E‐04 lb/ADTUBP [034] No 0% 1.03E‐02 0.04 1.03E‐02 0.04

STRU 20 EQUI 44 Brown Stock Decker Methanol HAP 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 3.00E‐02 lb/ADTUBP [034] No 0% 1.88E+00 8.21 1.88E+00 8.21

STRU 20 EQUI 44 Brown Stock Decker Methyl Isobutyl Ketone HAP 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 9.90E‐05 lb/ADTUBP [034] No 0% 6.19E‐03 0.03 6.19E‐03 0.03

STRU 20 EQUI 44 Brown Stock Decker Methylene Chloride HAP 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 7.00E‐05 lb/ADTUBP [034] No 0% 4.38E‐03 0.02 4.38E‐03 0.02

STRU 20 EQUI 44 Brown Stock Decker o‐Cresol HAP 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 1.70E‐02 lb/ADTUBP [034] No 0% 1.06E+00 4.65 1.06E+00 4.65

STRU 20 EQUI 44 Brown Stock Decker o‐Xylene HAP 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 1.55E‐04 lb/ADTUBP [034] No 0% 9.69E‐03 0.04 9.69E‐03 0.04

STRU 20 EQUI 44 Brown Stock Decker Phenol HAP 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 1.50E‐04 lb/ADTUBP [034] No 0% 9.38E‐03 0.04 9.38E‐03 0.04

STRU 20 EQUI 44 Brown Stock Decker Propionaldehyde HAP 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 1.36E‐03 lb/ADTUBP [034] No 0% 8.50E‐02 0.37 8.50E‐02 0.37

STRU 20 EQUI 44 Brown Stock Decker Styrene HAP 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 2.27E‐04 lb/ADTUBP [034] No 0% 1.42E‐02 0.06 1.42E‐02 0.06

STRU 20 EQUI 44 Brown Stock Decker Tetrachloroethylene HAP 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 6.50E‐04 lb/ADTUBP [034] No 0% 4.06E‐02 0.18 4.06E‐02 0.18

STRU 20 EQUI 44 Brown Stock Decker Toluene HAP 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 1.45E‐04 lb/ADTUBP [034] No 0% 9.09E‐03 0.04 9.09E‐03 0.04

STRU 20 EQUI 44 Brown Stock Decker Trichloroethylene HAP 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 8.36E‐04 lb/ADTUBP [034] No 0% 5.23E‐02 0.23 5.23E‐02 0.23

STRU 20 EQUI 44 Brown Stock Decker Sulfur ‐ Total Reduced TRS 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 1.20E‐01 lb/ADTUP [035] No 0% 7.50E+00 32.85 7.50E+00 32.85

STRU 20 EQUI 44 Brown Stock Decker Xylenes (mixed isomers)

HAP 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 3.94E‐04 lb/ADTUBP [034] No 0% 2.46E‐02 0.11 2.46E‐02 0.11

STRU 20 EQUI 44 Brown Stock Decker Sulfur Dioxide SO2 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 2.00E‐02 lb/ADTUP [035] No 0% 1.25E+00 5.48 1.25E+00 5.48

STRU 20 EQUI 44 Brown Stock Decker VOCs as C VOC 1,500 ADTUBP ADT/Day 547,500 ADTUBP ADT/year 2.00E‐01 lb/ADTUP [035] No 0% 1.25E+01 54.75 1.25E+01 54.75

STRU 126 EQUI 285 Dirty Hot Water Tanks 1,1,1‐Trichloroethane HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 2.90E‐06 lb/hr/tank [002] No 0% 2.90E‐06 1.27E‐05 2.90E‐06 1.27E‐05

STRU 126 EQUI 285 Dirty Hot Water Tanks 1,1,2‐Trichloroethane HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 1.15E‐05 lb/hr/tank [002] No 0% 1.15E‐05 5.04E‐05 1.15E‐05 5.04E‐05

STRU 126 EQUI 285 Dirty Hot Water Tanks 1,2,4‐Trichlorobenzene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 2.00E‐05 lb/hr/tank [002] No 0% 2.00E‐05 8.76E‐05 2.00E‐05 8.76E‐05

STRU 126 EQUI 285 Dirty Hot Water Tanks 1,2‐Dichloroethane HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 1.51E‐04 lb/hr/tank [002] No 0% 1.51E‐04 6.61E‐04 1.51E‐04 6.61E‐04

STRU 126 EQUI 285 Dirty Hot Water Tanks 1,3‐Butadiene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 4.97E‐05 lb/hr/tank [002] No 0% 4.97E‐05 2.18E‐04 4.97E‐05 2.18E‐04

Hourly Throughput Annual ThroughputLimited PotentialEmissions [1]

Controls?Max. Uncontrolled

Emissions [1]

C:\Users\bkruege\Desktop\Boise calcs.xlsxPTE ‐ Point Sources

Date Printed: 4/27/2016Page 1 of 21



(lb/Unit) Note Yes/No % (lb/hr) (tons/yr) (lb/hr) (tons/yr)



Emissions [1]

STRU 126 EQUI 285 Dirty Hot Water Tanks Acetaldehyde HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 4.74E‐04 lb/hr/tank [002] No 0% 4.74E‐04 2.08E‐03 4.74E‐04 2.08E‐03

STRU 126 EQUI 285 Dirty Hot Water Tanks Acrolein HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 1.36E‐04 lb/hr/tank [002] No 0% 1.36E‐04 5.96E‐04 1.36E‐04 5.96E‐04

STRU 126 EQUI 285 Dirty Hot Water Tanks Benzene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 3.99E‐05 lb/hr/tank [002] No 0% 3.99E‐05 1.75E‐04 3.99E‐05 1.75E‐04

STRU 126 EQUI 285 Dirty Hot Water Tanks Carbon Disulfide HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 9.99E‐03 lb/hr/tank [002] No 0% 9.99E‐03 4.38E‐02 9.99E‐03 4.38E‐02

STRU 126 EQUI 285 Dirty Hot Water Tanks Carbon Tetrachloride HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 6.80E‐06 lb/hr/tank [002] No 0% 6.80E‐06 2.98E‐05 6.80E‐06 2.98E‐05

STRU 126 EQUI 285 Dirty Hot Water Tanks Chlorobenzene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 3.75E‐06 lb/hr/tank [002] No 0% 3.75E‐06 1.64E‐05 3.75E‐06 1.64E‐05

STRU 126 EQUI 285 Dirty Hot Water Tanks Chloroform HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 8.34E‐07 lb/hr/tank [002] No 0% 8.34E‐07 3.65E‐06 8.34E‐07 3.65E‐06

STRU 126 EQUI 285 Dirty Hot Water Tanks Cumene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 7.67E‐04 lb/hr/tank [002] No 0% 7.67E‐04 3.36E‐03 7.67E‐04 3.36E‐03

STRU 126 EQUI 285 Dirty Hot Water Tanks Ethyl Benzene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 1.51E‐05 lb/hr/tank [002] No 0% 1.51E‐05 6.63E‐05 1.51E‐05 6.63E‐05

STRU 126 EQUI 285 Dirty Hot Water Tanks Formaldehyde HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 2.00E‐04 lb/hr/tank [002] No 0% 2.00E‐04 8.76E‐04 2.00E‐04 8.76E‐04

STRU 126 EQUI 285 Dirty Hot Water Tanks m,p‐Xylene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 2.30E‐04 lb/hr/tank [002] No 0% 2.30E‐04 1.01E‐03 2.30E‐04 1.01E‐03

STRU 126 EQUI 285 Dirty Hot Water Tanks Methanol HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 1.30E‐01 lb/hr/tank [002] No 0% 1.30E‐01 5.69E‐01 1.30E‐01 5.69E‐01

STRU 126 EQUI 285 Dirty Hot Water Tanks Methyl Isobutyl Ketone HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 2.90E‐04 lb/hr/tank [002] No 0% 2.90E‐04 1.27E‐03 2.90E‐04 1.27E‐03

STRU 126 EQUI 285 Dirty Hot Water Tanks Methylene Chloride HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 1.94E‐04 lb/hr/tank [002] No 0% 1.94E‐04 8.50E‐04 1.94E‐04 8.50E‐04

STRU 126 EQUI 285 Dirty Hot Water Tanks n‐Hexane HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 3.80E‐06 lb/hr/tank [002] No 0% 3.80E‐06 1.66E‐05 3.80E‐06 1.66E‐05

STRU 126 EQUI 285 Dirty Hot Water Tanks o‐Xylene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 4.50E‐04 lb/hr/tank [002] No 0% 4.50E‐04 1.97E‐03 4.50E‐04 1.97E‐03

STRU 126 EQUI 285 Dirty Hot Water Tanks Propionaldehyde HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 9.38E‐04 lb/hr/tank [002] No 0% 9.38E‐04 4.11E‐03 9.38E‐04 4.11E‐03

STRU 126 EQUI 285 Dirty Hot Water Tanks Styrene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 7.89E‐05 lb/hr/tank [002] No 0% 7.89E‐05 3.46E‐04 7.89E‐05 3.46E‐04

STRU 126 EQUI 285 Dirty Hot Water Tanks Tetrachloroethylene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 5.10E‐05 lb/hr/tank [002] No 0% 5.10E‐05 2.23E‐04 5.10E‐05 2.23E‐04

STRU 126 EQUI 285 Dirty Hot Water Tanks Toluene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 1.60E‐04 lb/hr/tank [002] No 0% 1.60E‐04 7.01E‐04 1.60E‐04 7.01E‐04

STRU 126 EQUI 285 Dirty Hot Water Tanks Trichloroethylene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 2.31E‐05 lb/hr/tank [002] No 0% 2.31E‐05 1.01E‐04 2.31E‐05 1.01E‐04

STRU 126 EQUI 285 Dirty Hot Water Tanks TRS as S TRS 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 2.46E‐01 lb/hr/tank [002] No 0% 2.46E‐01 1.08E+00 2.46E‐01 1.08E+00

STRU 126 EQUI 285 Dirty Hot Water Tanks Xylenes (mixed isomers)

HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 9.44E‐05 lb/hr/tank [002] No 0% 9.44E‐05 4.13E‐04 9.44E‐05 4.13E‐04

STRU 126 EQUI 285 Dirty Hot Water Tanks VOCs as C VOC 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 5.35E‐01 lb/hr/tank [002] No 0% 5.35E‐01 2.34E+00 5.35E‐01 2.34E+00

STRU 127 EQUI 259 14% Black Liquor Tank 1,1,1‐Trichloroethane HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 2.90E‐06 lb/hr/tank [002] No 0% 2.90E‐06 1.27E‐05 2.90E‐06 1.27E‐05

STRU 127 EQUI 259 14% Black Liquor Tank 1,1,2‐Trichloroethane HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 1.15E‐05 lb/hr/tank [002] No 0% 1.15E‐05 5.04E‐05 1.15E‐05 5.04E‐05

STRU 127 EQUI 259 14% Black Liquor Tank 1,2,4‐Trichlorobenzene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 2.00E‐05 lb/hr/tank [002] No 0% 2.00E‐05 8.76E‐05 2.00E‐05 8.76E‐05

STRU 127 EQUI 259 14% Black Liquor Tank 1,2‐Dichloroethane HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 1.51E‐04 lb/hr/tank [002] No 0% 1.51E‐04 6.61E‐04 1.51E‐04 6.61E‐04

STRU 127 EQUI 259 14% Black Liquor Tank 1,3‐Butadiene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 4.97E‐05 lb/hr/tank [002] No 0% 4.97E‐05 2.18E‐04 4.97E‐05 2.18E‐04

STRU 127 EQUI 259 14% Black Liquor Tank Acetaldehyde HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 4.74E‐04 lb/hr/tank [002] No 0% 4.74E‐04 2.08E‐03 4.74E‐04 2.08E‐03

STRU 127 EQUI 259 14% Black Liquor Tank Acrolein HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 1.36E‐04 lb/hr/tank [002] No 0% 1.36E‐04 5.96E‐04 1.36E‐04 5.96E‐04

STRU 127 EQUI 259 14% Black Liquor Tank Benzene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 3.99E‐05 lb/hr/tank [002] No 0% 3.99E‐05 1.75E‐04 3.99E‐05 1.75E‐04

STRU 127 EQUI 259 14% Black Liquor Tank Carbon Disulfide HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 9.99E‐03 lb/hr/tank [002] No 0% 9.99E‐03 4.38E‐02 9.99E‐03 4.38E‐02

STRU 127 EQUI 259 14% Black Liquor Tank Carbon Tetrachloride HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 6.80E‐06 lb/hr/tank [002] No 0% 6.80E‐06 2.98E‐05 6.80E‐06 2.98E‐05

STRU 127 EQUI 259 14% Black Liquor Tank Chlorobenzene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 3.75E‐06 lb/hr/tank [002] No 0% 3.75E‐06 1.64E‐05 3.75E‐06 1.64E‐05








Emissions [1]

STRU 127 EQUI 259 14% Black Liquor Tank Chloroform HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 8.34E‐07 lb/hr/tank [002] No 0% 8.34E‐07 3.65E‐06 8.34E‐07 3.65E‐06

STRU 127 EQUI 259 14% Black Liquor Tank Cumene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 7.67E‐04 lb/hr/tank [002] No 0% 7.67E‐04 3.36E‐03 7.67E‐04 3.36E‐03

STRU 127 EQUI 259 14% Black Liquor Tank Ethyl Benzene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 1.51E‐05 lb/hr/tank [002] No 0% 1.51E‐05 6.63E‐05 1.51E‐05 6.63E‐05

STRU 127 EQUI 259 14% Black Liquor Tank Formaldehyde HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 2.00E‐04 lb/hr/tank [002] No 0% 2.00E‐04 8.76E‐04 2.00E‐04 8.76E‐04

STRU 127 EQUI 259 14% Black Liquor Tank m,p‐Xylene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 2.30E‐04 lb/hr/tank [002] No 0% 2.30E‐04 1.01E‐03 2.30E‐04 1.01E‐03

STRU 127 EQUI 259 14% Black Liquor Tank Methanol HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 1.30E‐01 lb/hr/tank [002] No 0% 1.30E‐01 5.69E‐01 1.30E‐01 5.69E‐01

STRU 127 EQUI 259 14% Black Liquor Tank Methyl Isobutyl Ketone HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 2.90E‐04 lb/hr/tank [002] No 0% 2.90E‐04 1.27E‐03 2.90E‐04 1.27E‐03

STRU 127 EQUI 259 14% Black Liquor Tank Methylene Chloride HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 1.94E‐04 lb/hr/tank [002] No 0% 1.94E‐04 8.50E‐04 1.94E‐04 8.50E‐04

STRU 127 EQUI 259 14% Black Liquor Tank n‐Hexane HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 3.80E‐06 lb/hr/tank [002] No 0% 3.80E‐06 1.66E‐05 3.80E‐06 1.66E‐05

STRU 127 EQUI 259 14% Black Liquor Tank o‐Xylene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 4.50E‐04 lb/hr/tank [002] No 0% 4.50E‐04 1.97E‐03 4.50E‐04 1.97E‐03

STRU 127 EQUI 259 14% Black Liquor Tank Propionaldehyde HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 9.38E‐04 lb/hr/tank [002] No 0% 9.38E‐04 4.11E‐03 9.38E‐04 4.11E‐03

STRU 127 EQUI 259 14% Black Liquor Tank Styrene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 7.89E‐05 lb/hr/tank [002] No 0% 7.89E‐05 3.46E‐04 7.89E‐05 3.46E‐04

STRU 127 EQUI 259 14% Black Liquor Tank Tetrachloroethylene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 5.10E‐05 lb/hr/tank [002] No 0% 5.10E‐05 2.23E‐04 5.10E‐05 2.23E‐04

STRU 127 EQUI 259 14% Black Liquor Tank Toluene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 1.60E‐04 lb/hr/tank [002] No 0% 1.60E‐04 7.01E‐04 1.60E‐04 7.01E‐04

STRU 127 EQUI 259 14% Black Liquor Tank Trichloroethylene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 2.31E‐05 lb/hr/tank [002] No 0% 2.31E‐05 1.01E‐04 2.31E‐05 1.01E‐04

STRU 127 EQUI 259 14% Black Liquor Tank TRS as S TRS 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 2.46E‐01 lb/hr/tank [002] No 0% 2.46E‐01 1.08E+00 2.46E‐01 1.08E+00

STRU 127 EQUI 259 14% Black Liquor Tank Xylenes (mixed isomers)


STRU 127 EQUI 259 14% Black Liquor Tank VOCs as C VOC 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 5.35E‐01 lb/hr/tank [002] No 0% 5.35E‐01 2.34E+00 5.35E‐01 2.34E+00

STRU 128 EQUI 282 #9 & #10 Brown Stock High Density Storage Tank

1,1,2‐Trichloroethane HAP 2 hr/tank 2 Storage Tanks

17,520 hr/tank 2 Storage Tanks

6.20E‐05 lb/hr/tank [002] No 0% 1.24E‐04 5.43E‐04 1.24E‐04 5.43E‐04


Acetaldehyde HAP 2 hr/tank 2 Storage Tanks




Benzene HAP 2 hr/tank 2 Storage Tanks




Chlorobenzene HAP 2 hr/tank 2 Storage Tanks




Chloroform HAP 2 hr/tank 2 Storage Tanks




m,p‐Xylene HAP 2 hr/tank 2 Storage Tanks




Methanol HAP 2 hr/tank 2 Storage Tanks


2.40E‐01 lb/hr/tank [002] No 0% 4.80E‐01 2.10E+00 4.80E‐01 2.10E+00


Methyl Isobutyl Ketone HAP 2 hr/tank 2 Storage Tanks




n‐Hexane HAP 2 hr/tank 2 Storage Tanks




o‐Xylene HAP 2 hr/tank 2 Storage Tanks




Phenol HAP 2 hr/tank 2 Storage Tanks




Propionaldehyde HAP 2 hr/tank 2 Storage Tanks




Styrene HAP 2 hr/tank 2 Storage Tanks




Tetrachloroethylene HAP 2 hr/tank 2 Storage Tanks




Toluene HAP 2 hr/tank 2 Storage Tanks




Trichloroethylene HAP 2 hr/tank 2 Storage Tanks




TRS as S TRS 2 hr/tank 2 Storage Tanks


5.33E‐01 lb/hr/tank [002] No 0% 1.07E+00 4.67E+00 1.07E+00 4.67E+00








Emissions [1]


Xylenes (mixed isomers)

HAP 2 hr/tank 2 Storage Tanks




VOCs as C VOC 2 ADTP 2 Storage Tanks

17,520 ADTP 2 Storage Tanks

4.84E+00 lb/hr/tank [002] No 0% 9.68E+00 4.24E+01 9.68E+00 4.24E+01

STRU 132 EQUI 255 18% Liquor Tank 1,1,1‐Trichloroethane HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 2.90E‐06 lb/hr/tank [002] No 0% 2.90E‐06 1.27E‐05 2.90E‐06 1.27E‐05

STRU 132 EQUI 255 18% Liquor Tank 1,1,2‐Trichloroethane HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 1.15E‐05 lb/hr/tank [002] No 0% 1.15E‐05 5.04E‐05 1.15E‐05 5.04E‐05

STRU 132 EQUI 255 18% Liquor Tank 1,2,4‐Trichlorobenzene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 2.00E‐05 lb/hr/tank [002] No 0% 2.00E‐05 8.76E‐05 2.00E‐05 8.76E‐05

STRU 132 EQUI 255 18% Liquor Tank 1,2‐Dichloroethane HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 1.51E‐04 lb/hr/tank [002] No 0% 1.51E‐04 6.61E‐04 1.51E‐04 6.61E‐04

STRU 132 EQUI 255 18% Liquor Tank 1,3‐Butadiene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 4.97E‐05 lb/hr/tank [002] No 0% 4.97E‐05 2.18E‐04 4.97E‐05 2.18E‐04

STRU 132 EQUI 255 18% Liquor Tank Acetaldehyde HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 4.74E‐04 lb/hr/tank [002] No 0% 4.74E‐04 2.08E‐03 4.74E‐04 2.08E‐03

STRU 132 EQUI 255 18% Liquor Tank Acrolein HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 1.36E‐04 lb/hr/tank [002] No 0% 1.36E‐04 5.96E‐04 1.36E‐04 5.96E‐04

STRU 132 EQUI 255 18% Liquor Tank Benzene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 3.99E‐05 lb/hr/tank [002] No 0% 3.99E‐05 1.75E‐04 3.99E‐05 1.75E‐04

STRU 132 EQUI 255 18% Liquor Tank Carbon Disulfide HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 9.99E‐03 lb/hr/tank [002] No 0% 9.99E‐03 4.38E‐02 9.99E‐03 4.38E‐02

STRU 132 EQUI 255 18% Liquor Tank Carbon Tetrachloride HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 6.80E‐06 lb/hr/tank [002] No 0% 6.80E‐06 2.98E‐05 6.80E‐06 2.98E‐05

STRU 132 EQUI 255 18% Liquor Tank Chlorobenzene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 3.75E‐06 lb/hr/tank [002] No 0% 3.75E‐06 1.64E‐05 3.75E‐06 1.64E‐05

STRU 132 EQUI 255 18% Liquor Tank Chloroform HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 8.34E‐07 lb/hr/tank [002] No 0% 8.34E‐07 3.65E‐06 8.34E‐07 3.65E‐06

STRU 132 EQUI 255 18% Liquor Tank Cumene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 7.67E‐04 lb/hr/tank [002] No 0% 7.67E‐04 3.36E‐03 7.67E‐04 3.36E‐03

STRU 132 EQUI 255 18% Liquor Tank Ethyl Benzene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 1.51E‐05 lb/hr/tank [002] No 0% 1.51E‐05 6.63E‐05 1.51E‐05 6.63E‐05

STRU 132 EQUI 255 18% Liquor Tank Formaldehyde HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 2.00E‐04 lb/hr/tank [002] No 0% 2.00E‐04 8.76E‐04 2.00E‐04 8.76E‐04

STRU 132 EQUI 255 18% Liquor Tank m,p‐Xylene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 2.30E‐04 lb/hr/tank [002] No 0% 2.30E‐04 1.01E‐03 2.30E‐04 1.01E‐03

STRU 132 EQUI 255 18% Liquor Tank Methanol HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 1.30E‐01 lb/hr/tank [002] No 0% 1.30E‐01 5.69E‐01 1.30E‐01 5.69E‐01

STRU 132 EQUI 255 18% Liquor Tank Methyl Isobutyl Ketone HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 2.90E‐04 lb/hr/tank [002] No 0% 2.90E‐04 1.27E‐03 2.90E‐04 1.27E‐03

STRU 132 EQUI 255 18% Liquor Tank Methylene Chloride HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 1.94E‐04 lb/hr/tank [002] No 0% 1.94E‐04 8.50E‐04 1.94E‐04 8.50E‐04

STRU 132 EQUI 255 18% Liquor Tank n‐Hexane HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 3.80E‐06 lb/hr/tank [002] No 0% 3.80E‐06 1.66E‐05 3.80E‐06 1.66E‐05

STRU 132 EQUI 255 18% Liquor Tank o‐Xylene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 4.50E‐04 lb/hr/tank [002] No 0% 4.50E‐04 1.97E‐03 4.50E‐04 1.97E‐03

STRU 132 EQUI 255 18% Liquor Tank Propionaldehyde HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 9.38E‐04 lb/hr/tank [002] No 0% 9.38E‐04 4.11E‐03 9.38E‐04 4.11E‐03

STRU 132 EQUI 255 18% Liquor Tank Styrene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 7.89E‐05 lb/hr/tank [002] No 0% 7.89E‐05 3.46E‐04 7.89E‐05 3.46E‐04

STRU 132 EQUI 255 18% Liquor Tank Tetrachloroethylene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 5.10E‐05 lb/hr/tank [002] No 0% 5.10E‐05 2.23E‐04 5.10E‐05 2.23E‐04

STRU 132 EQUI 255 18% Liquor Tank Toluene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 1.60E‐04 lb/hr/tank [002] No 0% 1.60E‐04 7.01E‐04 1.60E‐04 7.01E‐04

STRU 132 EQUI 255 18% Liquor Tank Trichloroethylene HAP 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 2.31E‐05 lb/hr/tank [002] No 0% 2.31E‐05 1.01E‐04 2.31E‐05 1.01E‐04

STRU 132 EQUI 255 18% Liquor Tank TRS as S TRS 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 2.46E‐01 lb/hr/tank [002] No 0% 2.46E‐01 1.08E+00 2.46E‐01 1.08E+00

STRU 132 EQUI 255 18% Liquor Tank Xylenes (mixed isomers)


STRU 132 EQUI 255 18% Liquor Tank VOCs as C VOC 1 hr/tank Storage Tank 8,760 hr/tank Storage tank 5.35E‐01 lb/hr/tank [002] No 0% 5.35E‐01 2.34E+00 5.35E‐01 2.34E+00

STRU 150 EQUI 9 Recovery Furnace (BLS) 1,1,1‐Trichloroethane HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 5.90E‐07 lb/T BLS [003] No 0% 3.92E‐05 1.56E‐04 3.92E‐05 1.56E‐04

STRU 150 EQUI 9 Recovery Furnace (BLS) 1,1,2‐Trichloroethane HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.20E‐05 lb/T BLS [003] No 0% 7.98E‐04 3.18E‐03 7.98E‐04 3.18E‐03

STRU 150 EQUI 9 Recovery Furnace (BLS) 1,2,4‐Trichlorobenzene HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.50E‐04 lb/T BLS [003] No 0% 9.97E‐03 3.98E‐02 9.97E‐03 3.98E‐02

STRU 150 EQUI 9 Recovery Furnace (BLS) 1,2‐Dichloroethane HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.56E‐07 lb/T BLS [003] No 0% 1.04E‐05 4.14E‐05 1.04E‐05 4.14E‐05








Emissions [1]

STRU 150 EQUI 9 Recovery Furnace (BLS) 1,3‐Butadiene HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.59E‐04 lb/T BLS [003] No 0% 1.06E‐02 4.22E‐02 1.06E‐02 4.22E‐02

STRU 150 EQUI 9 Recovery Furnace (BLS) Acetaldehyde HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 3.70E‐03 lb/T BLS [003] No 0% 2.46E‐01 9.81E‐01 2.46E‐01 9.81E‐01

STRU 150 EQUI 9 Recovery Furnace (BLS) Antimony HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 3.20E‐07 lb/T BLS [003] No 0% 2.13E‐05 8.49E‐05 2.13E‐05 8.49E‐05

STRU 150 EQUI 9 Recovery Furnace (BLS) Arsenic HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 3.20E‐07 lb/T BLS [003] No 0% 2.13E‐05 8.49E‐05 2.13E‐05 8.49E‐05

STRU 150 EQUI 9 Recovery Furnace (BLS) Benzene HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 7.28E‐04 lb/T BLS [003] No 0% 4.84E‐02 1.93E‐01 4.84E‐02 1.93E‐01

STRU 150 EQUI 9 Recovery Furnace (BLS) Beryllium HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 4.06E‐07 lb/T BLS [003] No 0% 2.70E‐05 1.08E‐04 2.70E‐05 1.08E‐04

STRU 150 EQUI 9 Recovery Furnace (BLS) Cadmium HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 6.37E‐06 lb/T BLS [003] No 0% 4.23E‐04 1.69E‐03 4.23E‐04 1.69E‐03

STRU 150 EQUI 9 Recovery Furnace (BLS) Carbon Disulfide HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 6.60E‐04 lb/T BLS [003] No 0% 4.39E‐02 1.75E‐01 4.39E‐02 1.75E‐01

STRU 150 EQUI 9 Recovery Furnace (BLS) Carbon Tetrachloride HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.21E‐05 lb/T BLS [003] No 0% 8.04E‐04 3.21E‐03 8.04E‐04 3.21E‐03

STRU 150 EQUI 9 Recovery Furnace (BLS) Chlorobenzene HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.46E‐05 lb/T BLS [003] No 0% 9.70E‐04 3.87E‐03 9.70E‐04 3.87E‐03

STRU 150 EQUI 9 Recovery Furnace (BLS) Chloroform HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.42E‐05 lb/T BLS [003] No 0% 9.44E‐04 3.77E‐03 9.44E‐04 3.77E‐03

STRU 150 EQUI 9 Recovery Furnace (BLS) Methyl Chloride HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 5.37E‐05 lb/T BLS [003] No 0% 3.57E‐03 1.42E‐02 3.57E‐03 1.42E‐02

STRU 150 EQUI 9 Recovery Furnace (BLS) Chromium HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.64E‐05 lb/T BLS [003] No 0% 1.09E‐03 4.35E‐03 1.09E‐03 4.35E‐03

STRU 150 EQUI 9 Recovery Furnace (BLS) Cobalt HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.61E‐06 lb/T BLS [003] No 0% 1.07E‐04 4.27E‐04 1.07E‐04 4.27E‐04

STRU 150 EQUI 9 Recovery Furnace (BLS) Cumene HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.63E‐03 lb/T BLS [003] No 0% 1.08E‐01 4.32E‐01 1.08E‐01 4.32E‐01

STRU 150 EQUI 9 Recovery Furnace (BLS) Ethyl Benzene HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 4.62E‐05 lb/T BLS [003] No 0% 3.07E‐03 1.23E‐02 3.07E‐03 1.23E‐02

STRU 150 EQUI 9 Recovery Furnace (BLS) Formaldehyde HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 7.79E‐03 lb/T BLS [003] No 0% 5.18E‐01 2.07E+00 5.18E‐01 2.07E+00

STRU 150 EQUI 9 Recovery Furnace (BLS) Hexachlorobenzene HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.41E‐11 lb/T BLS [003] No 0% 9.34E‐10 3.73E‐09 9.34E‐10 3.73E‐09

STRU 150 EQUI 9 Recovery Furnace (BLS) Hydrochloric Acid HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 6.00E‐02 lb/T BLS [003] No 0% 3.99E+00 1.59E+01 3.99E+00 1.59E+01

STRU 150 EQUI 9 Recovery Furnace (BLS) Hydrogen Sulfide H2S 66 T RLS T BLS/hr 530,400 T RLS T BLS/year 2.00E‐02 lb/T BLS [006] No 0% 1.33E+00 5.30E+00 1.33E+00 5.30E+00

STRU 150 EQUI 9 Recovery Furnace (BLS) Lead HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 9.81E‐06 lb/T BLS [003] No 0% 6.52E‐04 2.60E‐03 6.52E‐04 2.60E‐03

STRU 150 EQUI 9 Recovery Furnace (BLS) m,p‐Xylene HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 4.40E‐04 lb/T BLS [003] No 0% 2.92E‐02 1.17E‐01 2.92E‐02 1.17E‐01

STRU 150 EQUI 9 Recovery Furnace (BLS) Mercury HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 3.38E‐06 lb/T BLS [003] No 0% 2.25E‐04 8.96E‐04 2.25E‐04 8.96E‐04

STRU 150 EQUI 9 Recovery Furnace (BLS) Methanol HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.80E‐02 lb/T BLS [003] No 0% 1.20E+00 4.77E+00 1.20E+00 4.77E+00

STRU 150 EQUI 9 Recovery Furnace (BLS) Methyl Isobutyl Ketone HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 4.70E‐04 lb/T BLS [003] No 0% 3.12E‐02 1.25E‐01 3.12E‐02 1.25E‐01

STRU 150 EQUI 9 Recovery Furnace (BLS) Methylene Chloride HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.79E‐04 lb/T BLS [003] No 0% 1.19E‐02 4.75E‐02 1.19E‐02 4.75E‐02

STRU 150 EQUI 9 Recovery Furnace (BLS) Naphthalene HAP 66 T RLS T BLS/hr 530,400 T RLS T BLS/year 1.64E‐04 lb/T BLS [006] No 0% 1.09E‐02 4.35E‐02 1.09E‐02 4.35E‐02

STRU 150 EQUI 9 Recovery Furnace (BLS) n‐Hexane HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.67E‐04 lb/T BLS [003] No 0% 1.11E‐02 4.43E‐02 1.11E‐02 4.43E‐02

STRU 150 EQUI 9 Recovery Furnace (BLS) Nickel HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 3.18E‐05 lb/T BLS [003] No 0% 2.11E‐03 8.43E‐03 2.11E‐03 8.43E‐03

STRU 150 EQUI 9 Recovery Furnace (BLS) o‐Xylene HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 5.00E‐04 lb/T BLS [003] No 0% 3.32E‐02 1.33E‐01 3.32E‐02 1.33E‐01

STRU 150 EQUI 9 Recovery Furnace (BLS) Phenol HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.37E‐02 lb/T BLS [003] No 0% 9.10E‐01 3.63E+00 9.10E‐01 3.63E+00

STRU 150 EQUI 9 Recovery Furnace (BLS) Phosphorus HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.96E‐04 lb/T BLS [003] No 0% 1.30E‐02 5.20E‐02 1.30E‐02 5.20E‐02

STRU 150 EQUI 9 Recovery Furnace (BLS) Propionaldehyde HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 6.52E‐03 lb/T BLS [003] No 0% 4.33E‐01 1.73E+00 4.33E‐01 1.73E+00

STRU 150 EQUI 9 Recovery Furnace (BLS) Selenium HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 2.50E‐06 lb/T BLS [003] No 0% 1.66E‐04 6.63E‐04 1.66E‐04 6.63E‐04

STRU 150 EQUI 9 Recovery Furnace (BLS) Styrene HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 9.07E‐05 lb/T BLS [003] No 0% 6.03E‐03 2.41E‐02 6.03E‐03 2.41E‐02








Emissions [1]

STRU 150 EQUI 9 Recovery Furnace (BLS) Tetrachloroethylene HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 2.24E‐05 lb/T BLS [003] No 0% 1.49E‐03 5.94E‐03 1.49E‐03 5.94E‐03

STRU 150 EQUI 9 Recovery Furnace (BLS) Toluene HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 2.96E‐04 lb/T BLS [003] No 0% 1.97E‐02 7.85E‐02 1.97E‐02 7.85E‐02

STRU 150 EQUI 9 Recovery Furnace (BLS) Trichloroethylene HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 7.90E‐07 lb/T BLS [003] No 0% 5.25E‐05 2.10E‐04 5.25E‐05 2.10E‐04

STRU 150 EQUI 9 Recovery Furnace (BLS) TRS as S TRS 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 2.59E‐02 lb/T BLS [003] No 0% 1.72 6.87 1.72 6.87

STRU 150 EQUI 9 Recovery Furnace (BLS) Vinyl Chloride HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 3.07E‐06 lb/T BLS [003] No 0% 2.04E‐04 8.14E‐04 2.04E‐04 8.14E‐04

STRU 150 EQUI 9 Recovery Furnace (BLS) Xylenes (mixed isomers)

HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 5.00E‐04 lb/T BLS [003] No 0% 3.32E‐02 1.33E‐01 3.32E‐02 1.33E‐01

STRU 150 EQUI 9 Recovery Furnace (BLS) Carbon Monoxide CO 5.38E+02 lb/hr (24‐hr avg)

[004] No 0% 538.00 538.00

STRU 150 EQUI 9 Recovery Furnace (BLS) Carbon Monoxide CO 2.29E+03 tons/year [004] No 0% 2,289.00 2,289.00

STRU 150 EQUI 9 Recovery Furnace (BLS) Nitrogen Oxides NOx 1.10E+02 lb/hr (30‐day roll)

[004] No 0% 110.00 481.80 110.00 481.80

STRU 150 EQUI 9 Recovery Furnace (BLS) PM (Condensable) PM (Condensable) 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.27E‐01 lb/T BLS [003] No 8.47 33.81 8.47 33.81

STRU 150 EQUI 9 Recovery Furnace (BLS) PM (filterable) PM (filterable) 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 3.74E‐01 lb/T BLS [003] Included in final emit

98.0% 1.24E+03 4.96E+03 24.86 99.18

STRU 150 EQUI 9 Recovery Furnace (BLS) PM (filterable) PM (filterable) 18.53 lb/hr [005] Included in final emit

98.0% 9.26E+02 4.06E+03 18.53 81.15

STRU 150 EQUI 9 Recovery Furnace (BLS) PM ‐ Total PM ‐ Total 27.00 lb/hr [005] Included in final emit

98.0% 1.35E+03 5.91E+03 27.00 118.26

STRU 150 EQUI 9 Recovery Furnace (BLS) PM10 (filterable) PM10 (filterable) 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 6.29E‐02 lb/T BLS [003] Included in final emit

94.0% 6.96E+01 2.78E+02 4.18 16.67

STRU 150 EQUI 9 Recovery Furnace (BLS) PM10 (filterable) PM10 (filterable) 10.73 lb/hr [005] Included in final emit

94.0% 1.79E+02 7.83E+02 10.73 46.99

STRU 150 EQUI 9 Recovery Furnace (BLS) PM10 ‐ Total PM10 19.20 lb/hr [005] Included in final emit

94.0% 3.20E+02 1.40E+03 19.20 84.10

STRU 150 EQUI 9 Recovery Furnace (BLS) PM2.5 (filterable) PM2.5 (filterable) 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 4.29E‐02 lb/T BLS [003] Included in final emit

94.0% 4.75E+01 1.90E+02 2.85 11.38

STRU 150 EQUI 9 Recovery Furnace (BLS) PM2.5 (filterable) PM2.5 (filterable) 10.73 lb/hr [005] Included in final emit

94.0% 1.79E+02 7.83E+02 10.73 46.99

STRU 150 EQUI 9 Recovery Furnace (BLS) PM2.5 ‐ Total PM2.5 19.20 lb/hr [005] Included in final emit

94.0% 3.20E+02 1.40E+03 19.20 84.10

STRU 150 EQUI 9 Recovery Furnace (BLS) Sulfur Dioxide SO2 106.20 lb/hr (3‐hour avg)

[004] No 0% 106.20 106.20

STRU 150 EQUI 9 Recovery Furnace (BLS) Sulfur Dioxide SO2 200.00 tons/year [004] No 0% 200.00 200.00

STRU 150 EQUI 9 Recovery Furnace (BLS) VOCs as C VOC 31.30 lb/hr (3‐hour avg)

[004] No 0% 31.30 137.09 31.30 137.09

STRU 150 EQUI 9 Recovery Furnace (BLS) Total Polycyclic aromatic hydr

PAH ‐ Total 66 T RLS T BLS/hr 530,400 T RLS T BLS/year 2.57E‐07 lb/T BLS [006] No 0% 1.71E‐05 6.82E‐05 1.71E‐05 6.82E‐05

STRU 110 EQUI 9 Recovery Furnace (BLS) TCDD ‐ TE CDD/F 66 T RLS T BLS/hr 530,400 T RLS T BLS/year 2.57E‐11 lb/T BLS [006] No 0% 1.71E‐09 6.82E‐09 1.71E‐09 6.82E‐09

STRU 110 EQUI 945 Smelt Dissolving Tank 1,1,1‐Trichloroethane HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 5.52E‐06 lb/T BLS [003] No 0% 3.67E‐04 1.46E‐03 3.67E‐04 1.46E‐03

STRU 110 EQUI 945 Smelt Dissolving Tank 1,1,2‐Trichloroethane HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.03E‐05 lb/T BLS [003] No 0% 6.85E‐04 2.73E‐03 6.85E‐04 2.73E‐03

STRU 110 EQUI 945 Smelt Dissolving Tank 1,2,4‐Trichlorobenzene HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 2.79E‐05 lb/T BLS [003] No 0% 1.85E‐03 7.40E‐03 1.85E‐03 7.40E‐03

STRU 110 EQUI 945 Smelt Dissolving Tank 1,2‐Dichloroethane HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 7.23E‐06 lb/T BLS [003] No 0% 4.80E‐04 1.92E‐03 4.80E‐04 1.92E‐03

STRU 110 EQUI 945 Smelt Dissolving Tank Acetaldehyde HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.11E‐03 lb/T BLS [003] No 0% 7.38E‐02 2.94E‐01 7.38E‐02 2.94E‐01

STRU 110 EQUI 945 Smelt Dissolving Tank Acrolein HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 2.26E‐04 lb/T BLS [003] No 0% 1.50E‐02 5.99E‐02 1.50E‐02 5.99E‐02

STRU 110 EQUI 945 Smelt Dissolving Tank Antimony HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.28E‐07 lb/T BLS [003] No 0% 8.51E‐06 3.39E‐05 8.51E‐06 3.39E‐05

STRU 110 EQUI 945 Smelt Dissolving Tank Arsenic HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 9.41E‐07 lb/T BLS [003] No 0% 6.25E‐05 2.50E‐04 6.25E‐05 2.50E‐04

STRU 110 EQUI 945 Smelt Dissolving Tank Benzene HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.61E‐05 lb/T BLS [003] No 0% 1.07E‐03 4.27E‐03 1.07E‐03 4.27E‐03

STRU 110 EQUI 945 Smelt Dissolving Tank Beryllium HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.11E‐07 lb/T BLS [003] No 0% 7.38E‐06 2.94E‐05 7.38E‐06 2.94E‐05

STRU 110 EQUI 945 Smelt Dissolving Tank Biphenyl HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 3.61E‐05 lb/T BLS [003] No 0% 2.40E‐03 9.57E‐03 2.40E‐03 9.57E‐03








Emissions [1]

STRU 110 EQUI 945 Smelt Dissolving Tank Bis(2‐Ethylhexyl)phthalate


STRU 110 EQUI 945 Smelt Dissolving Tank Bromomethane HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.30E‐05 lb/T BLS [003] No 0% 8.64E‐04 3.45E‐03 8.64E‐04 3.45E‐03

STRU 110 EQUI 945 Smelt Dissolving Tank Cadmium HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 5.20E‐07 lb/T BLS [003] No 0% 3.46E‐05 1.38E‐04 3.46E‐05 1.38E‐04

STRU 110 EQUI 945 Smelt Dissolving Tank Carbon Disulfide HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 3.35E‐05 lb/T BLS [003] No 0% 2.23E‐03 8.88E‐03 2.23E‐03 8.88E‐03

STRU 110 EQUI 945 Smelt Dissolving Tank Carbon Tetrachloride HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 3.90E‐06 lb/T BLS [003] No 0% 2.59E‐04 1.03E‐03 2.59E‐04 1.03E‐03

STRU 110 EQUI 945 Smelt Dissolving Tank Chlorobenzene HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.86E‐05 lb/T BLS [003] No 0% 1.24E‐03 4.93E‐03 1.24E‐03 4.93E‐03

STRU 110 EQUI 945 Smelt Dissolving Tank Chloroform HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 7.10E‐06 lb/T BLS [003] No 0% 4.72E‐04 1.88E‐03 4.72E‐04 1.88E‐03

STRU 110 EQUI 945 Smelt Dissolving Tank Methyl Chloride HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.12E‐04 lb/T BLS [003] No 0% 7.44E‐03 2.97E‐02 7.44E‐03 2.97E‐02

STRU 110 EQUI 945 Smelt Dissolving Tank Chromium HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 2.12E‐06 lb/T BLS [003] No 0% 1.41E‐04 5.62E‐04 1.41E‐04 5.62E‐04

STRU 110 EQUI 945 Smelt Dissolving Tank Cobalt HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.31E‐07 lb/T BLS [003] No 0% 8.71E‐06 3.47E‐05 8.71E‐06 3.47E‐05

STRU 110 EQUI 945 Smelt Dissolving Tank Cumene HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.43E‐04 lb/T BLS [003] No 0% 9.50E‐03 3.79E‐02 9.50E‐03 3.79E‐02

STRU 110 EQUI 945 Smelt Dissolving Tank Ethyl Benzene HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 8.69E‐06 lb/T BLS [003] No 0% 5.78E‐04 2.30E‐03 5.78E‐04 2.30E‐03

STRU 110 EQUI 945 Smelt Dissolving Tank Formaldehyde HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 3.15E‐04 lb/T BLS [003] No 0% 2.09E‐02 8.35E‐02 2.09E‐02 8.35E‐02

STRU 110 EQUI 945 Smelt Dissolving Tank Lead HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 6.90E‐07 lb/T BLS [003] No 0% 4.59E‐05 1.83E‐04 4.59E‐05 1.83E‐04

STRU 110 EQUI 945 Smelt Dissolving Tank m,p‐Xylene HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 5.95E‐05 lb/T BLS [003] No 0% 3.95E‐03 1.58E‐02 3.95E‐03 1.58E‐02

STRU 110 EQUI 945 Smelt Dissolving Tank Mercury HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.52E‐07 lb/T BLS [003] No 0% 1.01E‐05 4.03E‐05 1.01E‐05 4.03E‐05

STRU 110 EQUI 945 Smelt Dissolving Tank Methanol HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 7.33E‐02 lb/T BLS [003] No 0% 4.87E+00 1.94E+01 4.87E+00 1.94E+01

STRU 110 EQUI 945 Smelt Dissolving Tank Methyl Isobutyl Ketone HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.92E‐04 lb/T BLS [003] No 0% 1.28E‐02 5.09E‐02 1.28E‐02 5.09E‐02

STRU 110 EQUI 945 Smelt Dissolving Tank Methylene Chloride HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 3.90E‐05 lb/T BLS [003] No 0% 2.59E‐03 1.03E‐02 2.59E‐03 1.03E‐02

STRU 110 EQUI 945 Smelt Dissolving Tank Naphthalene HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 7.86E‐05 lb/T BLS [003] No 0% 5.22E‐03 2.08E‐02 5.22E‐03 2.08E‐02

STRU 110 EQUI 945 Smelt Dissolving Tank n‐Hexane HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 4.66E‐05 lb/T BLS [003] No 0% 3.10E‐03 1.24E‐02 3.10E‐03 1.24E‐02

STRU 110 EQUI 945 Smelt Dissolving Tank Nickel HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.67E‐06 lb/T BLS [003] No 0% 1.11E‐04 4.43E‐04 1.11E‐04 4.43E‐04

STRU 110 EQUI 945 Smelt Dissolving Tank o‐Xylene HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.10E‐04 lb/T BLS [003] No 0% 7.31E‐03 2.92E‐02 7.31E‐03 2.92E‐02

STRU 110 EQUI 945 Smelt Dissolving Tank Phenol HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 6.13E‐04 lb/T BLS [003] No 0% 4.07E‐02 1.63E‐01 4.07E‐02 1.63E‐01

STRU 110 EQUI 945 Smelt Dissolving Tank Phosphorus HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 2.40E‐05 lb/T BLS [003] No 0% 1.60E‐03 6.36E‐03 1.60E‐03 6.36E‐03

STRU 110 EQUI 945 Smelt Dissolving Tank Propionaldehyde HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 6.38E‐04 lb/T BLS [003] No 0% 4.24E‐02 1.69E‐01 4.24E‐02 1.69E‐01

STRU 110 EQUI 945 Smelt Dissolving Tank Selenium HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 3.79E‐07 lb/T BLS [003] No 0% 2.52E‐05 1.01E‐04 2.52E‐05 1.01E‐04

STRU 110 EQUI 945 Smelt Dissolving Tank Styrene HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 5.59E‐06 lb/T BLS [003] No 0% 3.72E‐04 1.48E‐03 3.72E‐04 1.48E‐03

STRU 110 EQUI 945 Smelt Dissolving Tank Tetrachloroethylene HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.71E‐05 lb/T BLS [003] No 0% 1.14E‐03 4.53E‐03 1.14E‐03 4.53E‐03

STRU 110 EQUI 945 Smelt Dissolving Tank Toluene HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 3.79E‐05 lb/T BLS [003] No 0% 2.52E‐03 1.01E‐02 2.52E‐03 1.01E‐02

STRU 110 EQUI 945 Smelt Dissolving Tank Trichloroethylene HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 2.76E‐05 lb/T BLS [003] No 0% 1.83E‐03 7.32E‐03 1.83E‐03 7.32E‐03

STRU 110 EQUI 945 Smelt Dissolving Tank TRS as S TRS 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.87E‐02 lb/T BLS [003] Included in final emit

50% 2.49E+00 9.92E+00 1.24E+00 4.96E+00

STRU 110 EQUI 945 Smelt Dissolving Tank Vinyl Acetate HAP 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 4.40E‐05 lb/T BLS [003] No 0% 2.92E‐03 1.17E‐02 2.92E‐03 1.17E‐02

STRU 110 EQUI 945 Smelt Dissolving Tank Xylenes (mixed isomers)


STRU 110 EQUI 945 Smelt Dissolving Tank Carbon Monoxide CO 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 8.22E‐03 lb/T BLS [003] No 0% 5.46E‐01 2.18E+00 5.46E‐01 2.18E+00








Emissions [1]

STRU 110 EQUI 945 Smelt Dissolving Tank PM (Condensable) PM (Condensable) 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.20E‐02 lb/T BLS [003] No 0% 0.80 3.19 0.80 3.19

STRU 110 EQUI 945 Smelt Dissolving Tank PM (filterable) PM (filterable) 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.46E‐01 lb/T BLS [003] Included in final emit

94.0% 1.62E+02 6.45E+02 9.70 38.72

STRU 110 EQUI 945 Smelt Dissolving Tank PM (filterable) PM (filterable) 6.50 lb/hr [007] Included in final emit

94.0% 1.08E+02 4.75E+02 6.50 28.47

STRU 110 EQUI 945 Smelt Dissolving Tank PM ‐ Total PM ‐ Total 7.30E+00 lb/hr [004] Included in final emit

94% 121.67 532.90 7.30 31.97

STRU 110 EQUI 945 Smelt Dissolving Tank PM10 (filterable) PM10 (filterable) 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.46E‐01 lb/T BLS [003] Included in final emit

84.0% 6.06E+01 2.42E+02 9.70 38.72

STRU 110 EQUI 945 Smelt Dissolving Tank PM10 (filterable) PM10 (filterable) 6.50 lb/hr [007] Included in final emit

84.0% 4.06E+01 1.78E+02 6.50 28.47

STRU 110 EQUI 945 Smelt Dissolving Tank PM10 ‐ Total PM10 7.30E+00 lb/hr [004] Included in final emit

84.0% 4.56E+01 2.00E+02 7.30 31.97

STRU 110 EQUI 945 Smelt Dissolving Tank PM2.5 (filterable) PM2.5 (filterable) 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.46E‐01 lb/T BLS [003] Included in final emit

84.0% 6.06E+01 2.42E+02 9.70 38.72

STRU 110 EQUI 945 Smelt Dissolving Tank PM2.5 (filterable) PM2.5 (filterable) 6.50 lb/hr [007] Included in final emit

84.0% 4.06E+01 1.78E+02 6.50 28.47

STRU 110 EQUI 945 Smelt Dissolving Tank PM2.5 ‐ Total PM2.5 7.30E+00 lb/hr [004] Included in final emit

84.0% 4.56E+01 2.00E+02 7.30 31.97

STRU 110 EQUI 945 Smelt Dissolving Tank Sulfur Dioxide SO2 4.30E+00 lb/hr [004] No 0% 4.30E+00 1.88E+01 4.30E+00 1.88E+01

STRU 110 EQUI 945 Smelt Dissolving Tank VOCs as C VOC 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 9.00E‐02 lb/T BLS [003] No 0% 5.98E+00 2.39E+01 5.98E+00 2.39E+01

STRU 110 EQUI 945 Smelt Dissolving Tank Nitrogen Oxides NOx 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 3.30E‐02 lb/T BLS [008] No 0% 2.19E+00 8.75E+00 2.19E+00 8.75E+00

STRU 110 EQUI 945 Smelt Dissolving Tank TRS as H2S TRS 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 3.30E‐02 lb/T BLS [008] Included in final emit

50% 4.39E+00 1.75E+01 2.19E+00 8.75E+00

STRU 110 EQUI 945 Smelt Dissolving Tank PAH ‐ Total PAH ‐ Total 66 T BLS T BLS/hr 530,400 T BLS T BLS/year 1.09E‐04 lb/T BLS [043] No 0% 7.24E‐03 2.89E‐02 7.24E‐03 2.89E‐02

STRU 141 EQUI 242 Green Liquor Clarifier Acetaldehyde HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/year 1.00E‐04 lb/T CaO [009] No 0% 1.17E‐03 5.11E‐03 1.17E‐03 5.11E‐03

STRU 141 EQUI 242 Green Liquor Clarifier Benzene HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/year 2.80E‐05 lb/T CaO [009] No 0% 3.27E‐04 1.43E‐03 3.27E‐04 1.43E‐03

STRU 141 EQUI 242 Green Liquor Clarifier m,p‐Xylene HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/year 1.90E‐04 lb/T CaO [009] No 0% 2.22E‐03 9.71E‐03 2.22E‐03 9.71E‐03

STRU 141 EQUI 242 Green Liquor Clarifier Methanol HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/year 1.30E‐01 lb/T CaO [009] No 0% 1.52E+00 6.64E+00 1.52E+00 6.64E+00

STRU 141 EQUI 242 Green Liquor Clarifier Methyl Isobutyl Ketone HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/year 1.10E‐05 lb/T CaO [009] No 0% 1.28E‐04 5.62E‐04 1.28E‐04 5.62E‐04

STRU 141 EQUI 242 Green Liquor Clarifier o‐Xylene HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/year 1.00E‐05 lb/T CaO [009] No 0% 1.17E‐04 5.11E‐04 1.17E‐04 5.11E‐04

STRU 141 EQUI 242 Green Liquor Clarifier Styrene HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/year 1.10E‐04 lb/T CaO [009] No 0% 1.28E‐03 5.62E‐03 1.28E‐03 5.62E‐03

STRU 141 EQUI 242 Green Liquor Clarifier Toluene HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/year 1.00E‐05 lb/T CaO [009] No 0% 1.17E‐04 5.11E‐04 1.17E‐04 5.11E‐04

STRU 141 EQUI 242 Green Liquor Clarifier VOCs as C VOC 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/year 6.60E‐02 lb/T CaO [009] No 0% 7.70E‐01 3.37E+00 7.70E‐01 3.37E+00

STRU 141 EQUI 242 Green Liquor Clarifier Hydrogen Sulfide H2S 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/hr 4.41E‐05 lb/T CaO [010] No 0% 5.15E‐04 2.25E‐03 5.15E‐04 2.25E‐03

STRU 141 EQUI 242 Green Liquor Clarifier Sulfur ‐ Total Reduced TRS 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/hr 4.41E‐04 lb/T CaO [010] No 0% 5.15E‐03 2.25E‐02 5.15E‐03 2.25E‐02

STRU 142 EQUI 241 Green Liquor Storage Tank 1,1,1‐Trichloroethane HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/hr 8.90E‐07 lb/T CaO [009] No 0% 1.04E‐05 4.55E‐05 1.04E‐05 4.55E‐05

STRU 142 EQUI 241 Green Liquor Storage Tank 1,1,2‐Trichloroethane HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/hr 6.50E‐06 lb/T CaO [009] No 0% 7.58E‐05 3.32E‐04 7.58E‐05 3.32E‐04

STRU 142 EQUI 241 Green Liquor Storage Tank 1,2‐Dichloroethane HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/hr 1.20E‐06 lb/T CaO [009] No 0% 1.40E‐05 6.13E‐05 1.40E‐05 6.13E‐05

STRU 142 EQUI 241 Green Liquor Storage Tank Acetaldehyde HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/hr 5.80E‐05 lb/T CaO [009] No 0% 6.77E‐04 2.96E‐03 6.77E‐04 2.96E‐03

STRU 142 EQUI 241 Green Liquor Storage Tank Acetone Other 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/hr 6.60E‐05 lb/T CaO [009] No 0% 7.70E‐04 3.37E‐03 7.70E‐04 3.37E‐03

STRU 142 EQUI 241 Green Liquor Storage Tank Benzene HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/hr 4.70E‐06 lb/T CaO [009] No 0% 5.48E‐05 2.40E‐04 5.48E‐05 2.40E‐04

STRU 142 EQUI 241 Green Liquor Storage Tank Chlorobenzene HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/hr 1.90E‐07 lb/T CaO [009] No 0% 2.22E‐06 9.71E‐06 2.22E‐06 9.71E‐06

STRU 142 EQUI 241 Green Liquor Storage Tank Chloroform HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/hr 2.00E‐06 lb/T CaO [009] No 0% 2.33E‐05 1.02E‐04 2.33E‐05 1.02E‐04

STRU 142 EQUI 241 Green Liquor Storage Tank Dimethyl Disulfide HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/hr 3.10E‐05 lb/T CaO [009] No 0% 3.62E‐04 1.58E‐03 3.62E‐04 1.58E‐03








Emissions [1]

STRU 142 EQUI 241 Green Liquor Storage Tank Dimethyl Sulfide DMS 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/hr 4.80E‐05 lb/T CaO [009] No 0% 5.60E‐04 2.45E‐03 5.60E‐04 2.45E‐03

STRU 142 EQUI 241 Green Liquor Storage Tank Methanol HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/hr 1.10E‐03 lb/T CaO [009] No 0% 1.28E‐02 5.62E‐02 1.28E‐02 5.62E‐02

STRU 142 EQUI 241 Green Liquor Storage Tank Methyl Ethyl Ketone HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/hr 2.00E‐05 lb/T CaO [009] No 0% 2.33E‐04 1.02E‐03 2.33E‐04 1.02E‐03

STRU 142 EQUI 241 Green Liquor Storage Tank Methyl Isobutyl Ketone HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/hr 2.90E‐06 lb/T CaO [009] No 0% 3.38E‐05 1.48E‐04 3.38E‐05 1.48E‐04

STRU 142 EQUI 241 Green Liquor Storage Tank Methyl Mercaptan Other 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/hr 2.10E‐06 lb/T CaO [009] No 0% 2.45E‐05 1.07E‐04 2.45E‐05 1.07E‐04

STRU 142 EQUI 241 Green Liquor Storage Tank n‐Hexane HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/hr 1.10E‐06 lb/T CaO [009] No 0% 1.28E‐05 5.62E‐05 1.28E‐05 5.62E‐05

STRU 142 EQUI 241 Green Liquor Storage Tank o‐Xylene HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/hr 3.40E‐07 lb/T CaO [009] No 0% 3.97E‐06 1.74E‐05 3.97E‐06 1.74E‐05

STRU 142 EQUI 241 Green Liquor Storage Tank Terpenes Other 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/hr 1.20E‐03 lb/T CaO [009] No 0% 1.40E‐02 6.13E‐02 1.40E‐02 6.13E‐02

STRU 142 EQUI 241 Green Liquor Storage Tank Tetrachloroethylene HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/hr 1.40E‐06 lb/T CaO [009] No 0% 1.63E‐05 7.15E‐05 1.63E‐05 7.15E‐05

STRU 142 EQUI 241 Green Liquor Storage Tank Toluene HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/hr 3.20E‐06 lb/T CaO [009] No 0% 3.73E‐05 1.64E‐04 3.73E‐05 1.64E‐04

STRU 142 EQUI 241 Green Liquor Storage Tank VOCs as C VOC 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/hr 1.40E‐03 lb/T CaO [009] No 0% 1.63E‐02 7.15E‐02 1.63E‐02 7.15E‐02

STRU 111 EQUI 13 Lime Kiln 1,2,4‐Trichlorobenzene HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 1.30E‐04 lb/T CaO [009] No 0% 1.52E‐03 6.64E‐03 1.52E‐03 6.64E‐03

STRU 111 EQUI 13 Lime Kiln 1,3‐Butadiene HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 6.94E‐05 lb/T CaO [009] No 0% 8.10E‐04 3.55E‐03 8.10E‐04 3.55E‐03

STRU 111 EQUI 13 Lime Kiln Acetaldehyde HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 6.42E‐03 lb/T CaO [009] No 0% 7.49E‐02 3.28E‐01 7.49E‐02 3.28E‐01

STRU 111 EQUI 13 Lime Kiln Acrolein HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 5.50E‐04 lb/T CaO [009] No 0% 6.42E‐03 2.81E‐02 6.42E‐03 2.81E‐02

STRU 111 EQUI 13 Lime Kiln Antimony HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 2.30E‐06 lb/T CaO [009] No 0% 2.68E‐05 1.18E‐04 2.68E‐05 1.18E‐04

STRU 111 EQUI 13 Lime Kiln Arsenic HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/yr 1.05E‐09 lb/T CaO [013] No 0% 1.22E‐08 5.34E‐08 1.22E‐08 5.34E‐08

STRU 111 EQUI 13 Lime Kiln Benzene HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 9.20E‐04 lb/T CaO [009] No 0% 1.07E‐02 4.70E‐02 1.07E‐02 4.70E‐02

STRU 111 EQUI 13 Lime Kiln Beryllium HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 5.80E‐07 lb/T CaO [009] No 0% 6.77E‐06 2.96E‐05 6.77E‐06 2.96E‐05

STRU 111 EQUI 13 Lime Kiln Cadmium HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/yr 2.09E‐09 lb/T CaO [013] No 0% 2.44E‐08 1.07E‐07 2.44E‐08 1.07E‐07

STRU 111 EQUI 13 Lime Kiln Carbon Disulfide HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 3.14E‐04 lb/T CaO [009] No 0% 3.66E‐03 1.60E‐02 3.66E‐03 1.60E‐02

STRU 111 EQUI 13 Lime Kiln Chlorobenzene HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 3.32E‐05 lb/T CaO [009] No 0% 3.87E‐04 1.69E‐03 3.87E‐04 1.69E‐03

STRU 111 EQUI 13 Lime Kiln Chloroform HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 9.98E‐05 lb/T CaO [009] No 0% 1.16E‐03 5.10E‐03 1.16E‐03 5.10E‐03

STRU 111 EQUI 13 Lime Kiln Methyl Chloride HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 1.70E‐03 lb/T CaO [009] No 0% 1.98E‐02 8.69E‐02 1.98E‐02 8.69E‐02

STRU 111 EQUI 13 Lime Kiln Chromium HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/yr 2.09E‐08 lb/T CaO [013] No 0% 2.44E‐07 1.07E‐06 2.44E‐07 1.07E‐06

STRU 111 EQUI 13 Lime Kiln Cobalt HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 2.29E‐06 lb/T CaO [009] No 0% 2.67E‐05 1.17E‐04 2.67E‐05 1.17E‐04

STRU 111 EQUI 13 Lime Kiln Cumene HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 1.63E‐03 lb/T CaO [009] No 0% 1.90E‐02 8.33E‐02 1.90E‐02 8.33E‐02

STRU 111 EQUI 13 Lime Kiln Ethyl Benzene HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 2.80E‐05 lb/T CaO [009] No 0% 3.27E‐04 1.43E‐03 3.27E‐04 1.43E‐03

STRU 111 EQUI 13 Lime Kiln Formaldehyde HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 4.99E‐03 lb/T CaO [009] No 0% 5.82E‐02 2.55E‐01 5.82E‐02 2.55E‐01

STRU 111 EQUI 13 Lime Kiln Hydrochloric Acid HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 1.90E‐03 lb/T CaO [009] No 0% 2.22E‐02 9.71E‐02 2.22E‐02 9.71E‐02

STRU 111 EQUI 13 Lime Kiln Hydrogen Sulfide H2S 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/yr 2.74E‐02 lb/T CaO [015] Included in final emit

50% 6.39E‐01 2.80E+00 3.20E‐01 1.40E+00

STRU 111 EQUI 13 Lime Kiln Lead HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/yr 2.25E‐07 lb/T CaO [014] No 0% 2.63E‐06 1.15E‐05 2.63E‐06 1.15E‐05

STRU 111 EQUI 13 Lime Kiln m,p‐Xylene HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 3.40E‐04 lb/T CaO [009] No 0% 3.97E‐03 1.74E‐02 3.97E‐03 1.74E‐02

STRU 111 EQUI 13 Lime Kiln Mercury HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/yr 5.10E‐09 lb/T CaO [013] No 0% 5.95E‐08 2.61E‐07 5.95E‐08 2.61E‐07

STRU 111 EQUI 13 Lime Kiln Methanol HAP 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/yr 4.58E‐08 lb/T CaO [013] No 0% 5.34E‐07 2.34E‐06 5.34E‐07 2.34E‐06








Emissions [1]

STRU 111 EQUI 13 Lime Kiln Methyl Isobutyl Ketone HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 2.60E‐04 lb/T CaO [009] No 0% 3.03E‐03 1.33E‐02 3.03E‐03 1.33E‐02

STRU 111 EQUI 13 Lime Kiln Methylene Chloride HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 1.30E‐04 lb/T CaO [009] No 0% 1.52E‐03 6.64E‐03 1.52E‐03 6.64E‐03

STRU 111 EQUI 13 Lime Kiln Naphthalene HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 4.62E‐04 lb/T CaO [009] No 0% 5.39E‐03 2.36E‐02 5.39E‐03 2.36E‐02

STRU 111 EQUI 13 Lime Kiln n‐Hexane HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 9.31E‐05 lb/T CaO [009] No 0% 1.09E‐03 4.76E‐03 1.09E‐03 4.76E‐03

STRU 111 EQUI 13 Lime Kiln Nickel HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 8.62E‐05 lb/T CaO [009] No 0% 1.01E‐03 4.40E‐03 1.01E‐03 4.40E‐03

STRU 111 EQUI 13 Lime Kiln o‐Xylene HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 3.40E‐04 lb/T CaO [009] No 0% 3.97E‐03 1.74E‐02 3.97E‐03 1.74E‐02

STRU 111 EQUI 13 Lime Kiln Phenol HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 8.90E‐03 lb/T CaO [009] No 0% 1.04E‐01 4.55E‐01 1.04E‐01 4.55E‐01

STRU 111 EQUI 13 Lime Kiln Phosphorus HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 2.80E‐03 lb/T CaO [009] No 0% 3.27E‐02 1.43E‐01 3.27E‐02 1.43E‐01

STRU 111 EQUI 13 Lime Kiln Propionaldehyde HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 4.90E‐03 lb/T CaO [009] No 0% 5.72E‐02 2.50E‐01 5.72E‐02 2.50E‐01

STRU 111 EQUI 13 Lime Kiln Selenium HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 3.00E‐06 lb/T CaO [009] No 0% 3.50E‐05 1.53E‐04 3.50E‐05 1.53E‐04

STRU 111 EQUI 13 Lime Kiln Styrene HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 6.34E‐05 lb/T CaO [009] No 0% 7.40E‐04 3.24E‐03 7.40E‐04 3.24E‐03

STRU 111 EQUI 13 Lime Kiln Sulfuric Acid (aerosol forms only)

Other 11.7 T CaO (Gas‐In) T CaO/hr 102,200 T CaO (Gas‐In) T CaO/yr 6.80E‐07 lb/T CaO(onGas)

[009] No 0% 7.93E‐06 3.47E‐05 7.93E‐06 3.47E‐05

STRU 111 EQUI 13 Lime Kiln Tetrachloroethylene HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 1.12E‐03 lb/T CaO [009] No 0% 1.31E‐02 5.72E‐02 1.31E‐02 5.72E‐02

STRU 111 EQUI 13 Lime Kiln Toluene HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 5.07E‐04 lb/T CaO [009] No 0% 5.92E‐03 2.59E‐02 5.92E‐03 2.59E‐02

STRU 111 EQUI 13 Lime Kiln Trichloroethylene HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 4.22E‐05 lb/T CaO [009] No 0% 4.92E‐04 2.16E‐03 4.92E‐04 2.16E‐03

STRU 111 EQUI 13 Lime Kiln TRS as S TRS 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 5.61E‐02 lb/T CaO [009] Included in final emit

50% 1.31E+00 5.73E+00 6.55E‐01 2.87E+00

STRU 111 EQUI 13 Lime Kiln Xylenes (mixed isomers)

HAP 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 7.28E‐04 lb/T CaO [009] No 0% 8.49E‐03 3.72E‐02 8.49E‐03 3.72E‐02

STRU 111 EQUI 13 Lime Kiln Carbon Monoxide CO 2.37E+01 lb/hr [004] No 0% 2.37E+01 1.04E+02 2.37E+01 1.04E+02

STRU 111 EQUI 13 Lime Kiln Nitrogen Oxides NOx 3.49E+01 lb/hr [004] No 0% 3.49E+01 1.53E+02 3.49E+01 1.53E+02

STRU 111 EQUI 13 Lime Kiln PM (Condensable) PM (Condensable) 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 9.51E‐02 lb/T CaO [009] No 0% 1.11E+00 4.86E+00 1.11E+00 4.86E+00

STRU 111 EQUI 13 Lime Kiln PM (filterable) PM (filterable) 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 1.16E+00 lb/T CaO [009] Included in final emit

94.0% 2.26E+02 9.88E+02 1.35E+01 5.93E+01

STRU 111 EQUI 13 Lime Kiln PM (filterable) PM (filterable) 1.16E+01 lb/hr [007] Included in final emit

94.0% 1.93E+02 8.46E+02 11.59 50.77

STRU 111 EQUI 13 Lime Kiln PM ‐ Total PM ‐ Total 1.27E+01 lb/T BLS [004] Included in final emit

94.0% 2.12E+02 9.27E+02 12.70 55.63

STRU 111 EQUI 13 Lime Kiln PM10 (filterable) PM10 (filterable) 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 1.16E+00 lb/T CaO [009] Included in final emit

84.0% 8.46E+01 3.70E+02 1.35E+01 5.93E+01

STRU 111 EQUI 13 Lime Kiln PM10 (filterable) PM10 (filterable) 1.16E+01 lb/hr [007] Included in final emit

84.0% 7.24E+01 3.17E+02 11.59 50.77

STRU 111 EQUI 13 Lime Kiln PM10 ‐ Total PM10 1.27E+01 lb/T BLS [004] Included in final emit

84.0% 7.94E+01 3.48E+02 12.70 55.63

STRU 111 EQUI 13 Lime Kiln PM2.5 (filterable) PM2.5 (filterable) 11.7 T CaO (Gas_a/or_Oil) T CaO/hr 102,200 T CaO (Gas_a/or_Oil) T CaO/yr 1.16E+00 lb/T CaO [009] Included in final emit

84.0% 8.46E+01 3.70E+02 1.35E+01 5.93E+01

STRU 111 EQUI 13 Lime Kiln PM2.5 (filterable) PM2.5 (filterable) 1.16E+01 lb/hr [007] Included in final emit

84.0% 7.24E+01 3.17E+02 11.59 50.77

STRU 111 EQUI 13 Lime Kiln PM2.5 ‐ Total PM2.5 1.27E+01 lb/T BLS [004] Included in final emit

84.0% 7.94E+01 3.48E+02 12.70 55.63

STRU 111 EQUI 13 Lime Kiln Sulfur Dioxide SO2 1.35E+01 lb/hr [004] Included in final emit

90% 1.35E+02 5.91E+02 13.50 59.13

STRU 111 EQUI 13 Lime Kiln VOCs as C VOC 1.14E+01 lb/hr [004] No 0% 1.14E+01 4.99E+01 1.14E+01 4.99E+01

STRU 111 EQUI 13 Lime Kiln PAH ‐ Total PAH ‐ Total 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/yr 4.73E‐05 lb/T CaO [043] No 0% 5.52E‐04 2.42E‐03 5.52E‐04 2.42E‐03

STRU 111 EQUI 13 Lime Kiln Dioxin/Furan (sum) CDD/F 11.7 T CaO T CaO/hr 102,200 T CaO T CaO/yr 1.67E‐09 lb/T CaO (median)

[044] No 0% 1.94E‐08 8.52E‐08 1.94E‐08 8.52E‐08

STRU 85 EQUI 49 Reburned Lime Bin PM ‐Total PM ‐ Total 25 tons lime/silo Silo 102,200 tons lime/silo Silo 4.20E‐01 lb/tons lime/silo

[052] Yes 99% 1.05E+01 2.15E+01 1.05E‐01 2.15E‐01

STRU 85 EQUI 49 Reburned Lime Bin PM10 (filterable) PM10 (filterable) 25 tons lime/silo Silo 102,200 tons lime/silo Silo 4.20E‐01 lb/tons lime/silo

[052] Yes 93% 1.05E+01 2.15E+01 7.35E‐01 1.50E+00








Emissions [1]

STRU 18 EQUI 15 Boiler #1 Arsenic HAP 0.3902 10e6 scf NatGas 10e6scf/hr 3,418 10e6 scf NatGas 10e6 scf/yr 2.20E‐04 lb/10e6 scf [017] No 0% 8.58E‐05 3.76E‐04 8.58E‐05 3.76E‐04

STRU 18 EQUI 15 Boiler #1 Benzene HAP 0.3902 10e6 scf NatGas 10e6scf/hr 3,418 10e6 scf NatGas 10e6 scf/yr 2.10E‐03 lb/10e6 scf [017] No 0% 8.19E‐04 3.59E‐03 8.19E‐04 3.59E‐03

STRU 18 EQUI 15 Boiler #1 Cadmium HAP 0.3902 10e6 scf NatGas 10e6scf/hr 3,418 10e6 scf NatGas 10e6 scf/yr 1.10E‐03 lb/10e6 scf [017] No 0% 4.29E‐04 1.88E‐03 4.29E‐04 1.88E‐03

STRU 18 EQUI 15 Boiler #1 Chromium HAP 0.3902 10e6 scf NatGas 10e6scf/hr 3,418 10e6 scf NatGas 10e6 scf/yr 1.40E‐03 lb/10e6 scf [017] No 0% 5.46E‐04 2.39E‐03 5.46E‐04 2.39E‐03

STRU 18 EQUI 15 Boiler #1 Cobalt HAP 0.3902 10e6 scf NatGas 10e6scf/hr 3,418 10e6 scf NatGas 10e6 scf/yr 8.40E‐05 lb/10e6 scf [017] No 0% 3.28E‐05 1.44E‐04 3.28E‐05 1.44E‐04

STRU 18 EQUI 15 Boiler #1 Formaldehyde HAP 0.3902 10e6 scf NatGas 10e6scf/hr 3,418 10e6 scf NatGas 10e6 scf/yr 7.50E‐02 lb/10e6 scf [017] No 0% 2.93E‐02 1.28E‐01 2.93E‐02 1.28E‐01

STRU 18 EQUI 15 Boiler #1 Lead HAP 0.3902 10e6 scf NatGas 10e6scf/hr 3,418 10e6 scf NatGas 10e6 scf/yr 5.00E‐04 lb/10e6 scf [017] No 0% 1.95E‐04 8.55E‐04 1.95E‐04 8.55E‐04

STRU 18 EQUI 15 Boiler #1 Mercury HAP 0.3902 10e6 scf NatGas 10e6scf/hr 3,418 10e6 scf NatGas 10e6 scf/yr 2.60E‐04 lb/10e6 scf [017] No 0% 1.01E‐04 4.44E‐04 1.01E‐04 4.44E‐04

STRU 18 EQUI 15 Boiler #1 Naphthalene HAP 0.3902 10e6 scf NatGas 10e6scf/hr 3,418 10e6 scf NatGas 10e6 scf/yr 6.10E‐04 lb/10e6 scf [017] No 0% 2.38E‐04 1.04E‐03 2.38E‐04 1.04E‐03

STRU 18 EQUI 15 Boiler #1 n‐Hexane HAP 0.3902 10e6 scf NatGas 10e6scf/hr 3,418 10e6 scf NatGas 10e6 scf/yr 1.80E+00 lb/10e6 scf [017] No 0% 7.02E‐01 3.08E+00 7.02E‐01 3.08E+00

STRU 18 EQUI 15 Boiler #1 Nickel HAP 0.3902 10e6 scf NatGas 10e6scf/hr 3,418 10e6 scf NatGas 10e6 scf/yr 2.10E‐03 lb/10e6 scf [017] No 0% 8.19E‐04 3.59E‐03 8.19E‐04 3.59E‐03

STRU 18 EQUI 15 Boiler #1 Selenium HAP 0.3902 10e6 scf NatGas 10e6scf/hr 3,418 10e6 scf NatGas 10e6 scf/yr 2.40E‐05 lb/10e6 scf [017] No 0% 9.36E‐06 4.10E‐05 9.36E‐06 4.10E‐05

STRU 18 EQUI 15 Boiler #1 Toluene HAP 0.3902 10e6 scf NatGas 10e6scf/hr 3,418 10e6 scf NatGas 10e6 scf/yr 3.40E‐03 lb/10e6 scf [017] No 0% 1.33E‐03 5.81E‐03 1.33E‐03 5.81E‐03

STRU 18 EQUI 15 Boiler #1 Nitrogen Oxides NOx 398 MMBtu MMBtu/Hr 3,486,480 MMBtu MMBtu/year 0.2 lb/MMBtu [020] No 0% 7.96E+01 3.49E+02 7.96E+01 3.49E+02

STRU 18 EQUI 15 Boiler #1 PM (Condensable) PM (Condensable) 0.3902 10e6 scf NatGas 10e6scf/hr 3,418 10e6 scf NatGas 10e6 scf/yr 5.70E+00 lb/10e6 scf [018] No 0% 2.22 9.74 2.22 9.74

STRU 18 EQUI 15 Boiler #1 PM (filterable) PM (filterable) 0.3902 10e6 scf NatGas 10e6scf/hr 3,418 10e6 scf NatGas 10e6 scf/yr 1.90E+00 lb/10e6 scf [017] No 0% 0.74 3.25 0.74 3.25

STRU 18 EQUI 15 Boiler #1 PM ‐ Total PM ‐ Total 398 MMBtu MMBtu/Hr 3,486,480 MMBtu MMBtu/year 7.45E‐03 lb/MMBtu (PTE as stated in

[018] No 0% 2.97 12.99 2.97 12.99

STRU 18 EQUI 15 Boiler #1 PM ‐ Total PM ‐ Total 398 MMBtu MMBtu/Hr 3,486,480 MMBtu MMBtu/year 6.00E‐01 lb/MMBtu (limit as stated

[022] No 0% 238.80 1045.94 238.80 1045.94

STRU 18 EQUI 15 Boiler #1 PM10 (filterable) PM10 (filterable) 0.3902 10e6 scf NatGas 10e6scf/hr 3,418 10e6 scf NatGas 10e6 scf/yr 1.90E+00 lb/10e6 scf [017] No 0% 0.74 3.25 0.74 3.25

STRU 18 EQUI 15 Boiler #1 PM10 ‐ Total PM10 398 MMBtu MMBtu/Hr 3,486,480 MMBtu MMBtu/year 7.45E‐03 lb/MMBtu (PTE as stated in

[018] No 0% 2.97 12.99 2.97 12.99

STRU 18 EQUI 15 Boiler #1 PM10 ‐ Total PM10 398 MMBtu MMBtu/Hr 3,486,480 MMBtu MMBtu/year 6.00E‐01 lb/MMBtu (limit as stated

[022] No 0% 238.80 1045.94 238.80 1045.94

STRU 18 EQUI 15 Boiler #1 PM2.5 (filterable) PM2.5 (filterable) 0.3902 10e6 scf NatGas 10e6scf/hr 3,418 10e6 scf NatGas 10e6 scf/yr 1.90E+00 lb/10e6 scf [017] No 0% 0.74 3.25 0.74 3.25

STRU 18 EQUI 15 Boiler #1 PM2.5 ‐ Total PM2.5 398 MMBtu MMBtu/Hr 3,486,480 MMBtu MMBtu/year 7.45E‐03 lb/MMBtu [018] No 0% 2.97 12.99 2.97 12.99

STRU 18 EQUI 15 Boiler #1 PM2.5 ‐ Total PM2.5 398 MMBtu MMBtu/Hr 3,486,480 MMBtu MMBtu/year 6.00E‐01 lb/MMBtu [022] No 0% 238.80 1045.94 238.80 1045.94

STRU 18 EQUI 15 Boiler #1 CO CO 0.3902 10e6 scf NatGas 10e6scf/hr 3,418 10e6 scf NatGas 10e6 scf/yr 8.40E+01 lb/10e6 scf [018] No 0% 32.78 143.56 32.78 143.56

STRU 18 EQUI 15 Boiler #2 VOC VOC 398 MMBtu MMBtu/Hr 3,486,480 MMBtu MMBtu/year 5.40E‐03 lb/MMBtu AP‐42 No 0% 2.15 9.41 2.15 9.41

STRU 18 EQUI 15 Boiler #1 Sulfur Dioxide SO2 0.3902 10e6 scf NatGas 10e6scf/hr 3,418 10e6 scf NatGas 10e6 scf/yr 6.00E‐01 lb/10e6 scf [017] No 0% 2.34E‐01 1.03E+00 2.34E‐01 1.03E+00

STRU 18 EQUI 15 Boiler #1 PAH ‐ Total PAH ‐ Total 0.3902 10e6 scf NatGas 10e6scf/hr 3,418 10e6 scf NatGas 10e6 scf/yr 1.76E‐05 lb/e3 scf [043] No 0% 6.87E‐03 3.01E‐02 6.87E‐03 3.01E‐02

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) 1,1,1‐Trichloroethane HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 3.93E‐05 lb/10e6 Btu [023] No 0% 1.56E‐02 7.01E‐02 1.56E‐02 7.01E‐02

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) 1,2‐Dichloroethane HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 2.92E‐05 lb/10e6 Btu [023] No 0% 1.16E‐02 5.21E‐02 1.16E‐02 5.21E‐02

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) 1,4‐Dichlorobenzene HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 2.79E‐04 lb/10e6 Btu [023] No 0% 1.11E‐01 4.97E‐01 1.11E‐01 4.97E‐01

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) 2,4,6‐Trichlorophenol HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 2.76E‐07 lb/10e6 Btu [023] No 0% 1.10E‐04 4.92E‐04 1.10E‐04 4.92E‐04

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) 2,4‐Dinitrophenol HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 1.30E‐07 lb/10e6 Btu [023] No 0% 5.17E‐05 2.32E‐04 5.17E‐05 2.32E‐04

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) 2,4‐Dinitrotoluene HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 9.42E‐07 lb/10e6 Btu [023] No 0% 3.75E‐04 1.68E‐03 3.75E‐04 1.68E‐03

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Acetaldehyde HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 1.57E‐04 lb/10e6 Btu [023] No 0% 6.25E‐02 2.80E‐01 6.25E‐02 2.80E‐01








Emissions [1]

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Acetophenone HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 1.84E‐06 lb/10e6 Btu [023] No 0% 7.32E‐04 3.28E‐03 7.32E‐04 3.28E‐03

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Acrolein HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 1.27E‐04 lb/10e6 Btu [023] No 0% 5.05E‐02 2.26E‐01 5.05E‐02 2.26E‐01

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Antimony HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 1.55E‐07 lb/10e6 Btu [023] No 0% 6.17E‐05 2.76E‐04 6.17E‐05 2.76E‐04

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Arsenic HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 3.69E‐07 lb/10e6 Btu [023] No 0% 1.47E‐04 6.58E‐04 1.47E‐04 6.58E‐04

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Benzene HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 2.35E‐04 lb/10e6 Btu [023] No 0% 9.35E‐02 4.19E‐01 9.35E‐02 4.19E‐01

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Benzo[a]pyrene PAH 37.0 ton hog fuel T burned/hr 324,120 ton hog fuel T burned/year

2.17E‐07 lb/T Burned [026] No 0% 8.03E‐06 3.52E‐05 8.03E‐06 3.52E‐05

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Beryllium HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 7.11E‐09 lb/10e6 Btu [023] No 0% 2.83E‐06 1.27E‐05 2.83E‐06 1.27E‐05

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Bis(2‐Ethylhexyl)phthalate

HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 4.65E‐08 lb/10e6 Btu [023] No 0% 1.85E‐05 8.29E‐05 1.85E‐05 8.29E‐05

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Bromomethane HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 3.67E‐06 lb/10e6 Btu [023] No 0% 1.46E‐03 6.54E‐03 1.46E‐03 6.54E‐03

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Cadmium HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 3.90E‐07 lb/10e6 Btu [023] No 0% 1.55E‐04 6.95E‐04 1.55E‐04 6.95E‐04

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Carbon Disulfide HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 1.25E‐04 lb/10e6 Btu [023] No 0% 4.98E‐02 2.23E‐01 4.98E‐02 2.23E‐01

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Carbon Tetrachloride HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 1.16E‐05 lb/10e6 Btu [023] No 0% 4.62E‐03 2.07E‐02 4.62E‐03 2.07E‐02

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Chlorobenzene HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 1.66E‐05 lb/10e6 Btu [023] No 0% 6.61E‐03 2.96E‐02 6.61E‐03 2.96E‐02

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Chloroform HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 2.55E‐06 lb/10e6 Btu [023] No 0% 1.01E‐03 4.55E‐03 1.01E‐03 4.55E‐03

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Methyl Chloride HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 2.66E‐05 lb/10e6 Btu [023] No 0% 1.06E‐02 4.73E‐02 1.06E‐02 4.73E‐02

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Chromium HAP 37.0 ton hog fuel T burned/hr 324,120 ton hog fuel T burned/year


STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Cobalt HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 1.03E‐07 lb/10e6 Btu [023] No 0% 4.10E‐05 1.83E‐04 4.10E‐05 1.83E‐04

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Cumene HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 1.77E‐05 lb/10e6 Btu [023] No 0% 7.04E‐03 3.16E‐02 7.04E‐03 3.16E‐02

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Ethyl Benzene HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 3.13E‐05 lb/10e6 Btu [023] No 0% 1.25E‐02 5.58E‐02 1.25E‐02 5.58E‐02

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Formaldehyde HAP 37.0 ton hog fuel T burned/hr 324,120 ton hog fuel T burned/year


STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Hexachlorobenzene HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 1.03E‐06 lb/10e6 Btu [023] No 0% 4.10E‐04 1.84E‐03 4.10E‐04 1.84E‐03

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Hydrochloric Acid HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 3.46E‐04 lb/10e6 Btu [023] No 0% 1.38E‐01 6.17E‐01 1.38E‐01 6.17E‐01

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Hydrogen Fluoride HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 7.47E‐05 lb/10e6 Btu [023] No 0% 2.97E‐02 1.33E‐01 2.97E‐02 1.33E‐01

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Lead HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 1.97E‐06 lb/10e6 Btu [023] No 0% 7.85E‐04 3.52E‐03 7.85E‐04 3.52E‐03

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Lead HAP 37.0 ton hog fuel T burned/hr 324,120 ton hog fuel T burned/year


STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) m,p‐Xylene HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 2.79E‐06 lb/10e6 Btu [023] No 0% 1.11E‐03 4.97E‐03 1.11E‐03 4.97E‐03

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Mercury HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 6.26E‐07 lb/10e6 Btu [023] No 0% 2.49E‐04 1.12E‐03 2.49E‐04 1.12E‐03

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Mercury HAP 37.0 ton hog fuel T burned/hr 324,120 ton hog fuel T burned/year


STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Methanol HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 4.82E‐04 lb/10e6 Btu [023] No 0% 1.92E‐01 8.59E‐01 1.92E‐01 8.59E‐01

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Methyl Isobutyl Ketone HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 4.45E‐04 lb/10e6 Btu [023] No 0% 1.77E‐01 7.93E‐01 1.77E‐01 7.93E‐01

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Methylene Chloride HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 2.82E‐05 lb/10e6 Btu [023] No 0% 1.12E‐02 5.03E‐02 1.12E‐02 5.03E‐02

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Naphthalene HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 8.13E‐06 lb/10e6 Btu [023] No 0% 3.24E‐03 1.45E‐02 3.24E‐03 1.45E‐02

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) n‐Hexane HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 2.88E‐04 lb/10e6 Btu [023] No 0% 1.15E‐01 5.13E‐01 1.15E‐01 5.13E‐01

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Nickel HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 1.58E‐06 lb/10e6 Btu [023] No 0% 6.29E‐04 2.82E‐03 6.29E‐04 2.82E‐03

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) o‐Xylene HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 2.61E‐06 lb/10e6 Btu [023] No 0% 1.04E‐03 4.65E‐03 1.04E‐03 4.65E‐03








Emissions [1]

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Pentachlorophenol HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 4.48E‐08 lb/10e6 Btu [023] No 0% 1.78E‐05 7.99E‐05 1.78E‐05 7.99E‐05

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Phenol HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 1.53E‐05 lb/10e6 Btu [023] No 0% 6.09E‐03 2.73E‐02 6.09E‐03 2.73E‐02

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Phosphorus HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 3.10E‐04 lb/10e6 Btu [023] No 0% 1.23E‐01 5.53E‐01 1.23E‐01 5.53E‐01

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Propionaldehyde HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 2.14E‐05 lb/10e6 Btu [023] No 0% 8.52E‐03 3.81E‐02 8.52E‐03 3.81E‐02

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Selenium HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 9.22E‐07 lb/10e6 Btu [023] No 0% 3.67E‐04 1.64E‐03 3.67E‐04 1.64E‐03

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Styrene HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 1.54E‐05 lb/10e6 Btu [023] No 0% 6.13E‐03 2.75E‐02 6.13E‐03 2.75E‐02

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Tetrachloroethene HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 2.46E‐05 lb/10e6 Btu [023] No 0% 9.80E‐03 4.39E‐02 9.80E‐03 4.39E‐02

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Toluene HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 3.67E‐06 lb/10e6 Btu [023] No 0% 1.46E‐03 6.54E‐03 1.46E‐03 6.54E‐03

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Trichloroethylene HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 1.99E‐05 lb/10e6 Btu [023] No 0% 7.90E‐03 3.54E‐02 7.90E‐03 3.54E‐02

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Vinyl Chloride HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 1.84E‐05 lb/10e6 Btu [023] No 0% 7.32E‐03 3.28E‐02 7.32E‐03 3.28E‐02

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Xylenes (mixed isomers)

HAP 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 5.22E‐06 lb/10e6 Btu [023] No 0% 2.08E‐03 9.30E‐03 2.08E‐03 9.30E‐03

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) PAH ‐ Total PAH ‐ Total 37.0 ton hog fuel T burned/hr 324,120 ton hog fuel T burned/year


STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) TCDD ‐ TE Other 37.0 ton hog fuel T burned/hr 324,120 ton hog fuel T burned/year


STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Sulfur Dioxide SO2 3.95E+01 lb/hr [004] No 0% 3.95E+01 1.73E+02 3.95E+01 1.73E+02

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) PM (Condensable) PM (Condensable) 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 5.86E‐03 lb/10e6 Btu [023] No 0% 2.33E+00 1.05E+01 2.33E+00 1.05E+01

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) PM (filterable) PM (filterable) 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 5.40E‐02 lb/10e6 Btu [023] Included in final emit

98.00% 1.07E+03 4.81E+03 2.15E+01 9.63E+01

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) PM (filterable) PM (filterable) 1.07E+01 lbs/hr [027] Included in final emit

98.00% 5.33E+02 2.34E+03 1.07E+01 4.67E+01

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) PM ‐ Total PM ‐ Total 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 5.99E‐02 lb/10e6 Btu [023] Included in final emit

98.00% 1.19E+03 5.34E+03 2.38E+01 1.07E+02

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) PM ‐ Total PM ‐ Total 1.30E+01 lbs/hr [004] Included in final emit

98.00% 6.50E+02 2.85E+03 1.30E+01 5.69E+01

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) PM10 (filterable) PM10 (filterable) 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 4.00E‐02 lb/10e6 Btu [023] Included in final emit

94.00% 2.65E+02 1.19E+03 1.59E+01 7.13E+01

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) PM10 (filterable) PM10 (filterable) 9.37E+00 lbs/hr [027] Included in final emit

94.00% 1.56E+02 6.84E+02 9.37E+00 4.10E+01

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) PM10 ‐ Total PM10 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 4.59E‐02 lbs/hr [023] Included in final emit

94.00% 7.64E‐01 3.35E+00 4.59E‐02 2.01E‐01

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) PM10 ‐ Total PM10 1.17E+01 lbs/hr [004] Included in final emit

94.00% 1.95E+02 8.54E+02 1.17E+01 5.12E+01

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) PM2.5 (filterable) PM2.5 (filterable) 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 3.51E‐02 lb/10e6 Btu [023] Included in final emit

94.00% 2.33E+02 1.04E+03 1.40E+01 6.26E+01

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) PM2.5 (filterable) PM2.5 (filterable) 9.37E+00 lbs/hr [027] Included in final emit

94.00% 1.56E+02 6.84E+02 9.37E+00 4.10E+01

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) PM2.5 ‐ Total PM2.5 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 4.10E‐02 lbs/hr [023] Included in final emit

94.00% 6.83E‐01 2.99E+00 4.10E‐02 1.79E‐01

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) VOC as C VOC 4.02E+01 lbs/hr measured as C

[004] No 0% 4.02E+01 1.76E+02 4.02E+01 1.76E+02

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Carbon Monoxide CO 8.00E+02 lbs/hr (1‐hour average)

[024] No 0% 800.00 800.00

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Carbon Monoxide CO 2.00E+02 lbs/hr (12‐month rolling

[024] No 0% 876.00 876.00

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Nitrogen Oxides NOx 1.00E+02 lbs/hr using 30‐day rolling

[004] No 0% 100.20 438.88 100.20 438.88

STRU 146 EQUI 16 Boiler #2 (Biomass/sludge) Dioxin/Furan (sum) CDD/F 398.0 10e6 Btu Wood MMBtu/Hr 3,565,320 10e6 Btu Wood MMBtu/year 1.39E‐10 lb/MMBtu (median)

[044] No 0% 5.53E‐08 2.48E‐07 5.53E‐08 2.48E‐07

STRU 147 EQUI 17 Boiler #3 Arsenic HAP 0.3657 10e6 scf NatGas 10e6scf/hr 3,204 10e6 scf NatGas 10e6 scf/yr 2.20E‐04 lb/10e6 scf [017] No 0% 8.05E‐05 3.52E‐04 8.05E‐05 3.52E‐04

STRU 147 EQUI 17 Boiler #3 Benzene HAP 0.3657 10e6 scf NatGas 10e6scf/hr 3,204 10e6 scf NatGas 10e6 scf/yr 2.10E‐03 lb/10e6 scf [017] No 0% 7.68E‐04 3.36E‐03 7.68E‐04 3.36E‐03

STRU 147 EQUI 17 Boiler #3 Cadmium HAP 0.3657 10e6 scf NatGas 10e6scf/hr 3,204 10e6 scf NatGas 10e6 scf/yr 1.10E‐03 lb/10e6 scf [017] No 0% 4.02E‐04 1.76E‐03 4.02E‐04 1.76E‐03

STRU 147 EQUI 17 Boiler #3 Chromium HAP 0.3657 10e6 scf NatGas 10e6scf/hr 3,204 10e6 scf NatGas 10e6 scf/yr 1.40E‐03 lb/10e6 scf [017] No 0% 5.12E‐04 2.24E‐03 5.12E‐04 2.24E‐03








Emissions [1]

STRU 147 EQUI 17 Boiler #3 Cobalt HAP 0.3657 10e6 scf NatGas 10e6scf/hr 3,204 10e6 scf NatGas 10e6 scf/yr 8.40E‐05 lb/10e6 scf [017] No 0% 3.07E‐05 1.35E‐04 3.07E‐05 1.35E‐04

STRU 147 EQUI 17 Boiler #3 Formaldehyde HAP 0.3657 10e6 scf NatGas 10e6scf/hr 3,204 10e6 scf NatGas 10e6 scf/yr 7.50E‐02 lb/10e6 scf [017] No 0% 2.74E‐02 1.20E‐01 2.74E‐02 1.20E‐01

STRU 147 EQUI 17 Boiler #3 Lead HAP 0.3657 10e6 scf NatGas 10e6scf/hr 3,204 10e6 scf NatGas 10e6 scf/yr 5.00E‐04 lb/10e6 scf [017] No 0% 1.83E‐04 8.01E‐04 1.83E‐04 8.01E‐04

STRU 147 EQUI 17 Boiler #3 Mercury HAP 0.3657 10e6 scf NatGas 10e6scf/hr 3,204 10e6 scf NatGas 10e6 scf/yr 2.60E‐04 lb/10e6 scf [017] No 0% 9.51E‐05 4.16E‐04 9.51E‐05 4.16E‐04

STRU 147 EQUI 17 Boiler #3 Naphthalene HAP 0.3657 10e6 scf NatGas 10e6scf/hr 3,204 10e6 scf NatGas 10e6 scf/yr 6.10E‐04 lb/10e6 scf [017] No 0% 2.23E‐04 9.77E‐04 2.23E‐04 9.77E‐04

STRU 147 EQUI 17 Boiler #3 n‐Hexane HAP 0.3657 10e6 scf NatGas 10e6scf/hr 3,204 10e6 scf NatGas 10e6 scf/yr 1.80E+00 lb/10e6 scf [017] No 0% 6.58E‐01 2.88E+00 6.58E‐01 2.88E+00

STRU 147 EQUI 17 Boiler #3 Nickel HAP 0.3657 10e6 scf NatGas 10e6scf/hr 3,204 10e6 scf NatGas 10e6 scf/yr 2.10E‐03 lb/10e6 scf [017] No 0% 7.68E‐04 3.36E‐03 7.68E‐04 3.36E‐03

STRU 147 EQUI 17 Boiler #3 Selenium HAP 0.3657 10e6 scf NatGas 10e6scf/hr 3,204 10e6 scf NatGas 10e6 scf/yr 2.40E‐05 lb/10e6 scf [017] No 0% 8.78E‐06 3.84E‐05 8.78E‐06 3.84E‐05

STRU 147 EQUI 17 Boiler #3 Toluene HAP 0.3657 10e6 scf NatGas 10e6scf/hr 3,204 10e6 scf NatGas 10e6 scf/yr 3.40E‐03 lb/10e6 scf [017] No 0% 1.24E‐03 5.45E‐03 1.24E‐03 5.45E‐03

STRU 147 EQUI 17 Boiler #3 Nitrogen Oxides NOx 373 MMBtu MMBtu/Hr 3,267,480 MMBtu MMBtu/year 5.00E‐02 lbs/million Btu heat input

[022] No 0% 1.87E+01 8.17E+01 1.87E+01 8.17E+01

STRU 147 EQUI 17 Boiler #3 PM (Condensable) PM (Condensable) 0.3657 10e6 scf NatGas 10e6scf/hr 3,204 10e6 scf NatGas 10e6 scf/yr 5.70E+00 lb/10e6 scf [018] No 0% 2.08 9.13 2.08 9.13

STRU 147 EQUI 17 Boiler #3 PM (filterable) PM (filterable) 0.3657 10e6 scf NatGas 10e6scf/hr 3,204 10e6 scf NatGas 10e6 scf/yr 1.90E+00 lb/10e6 scf [017] No 0% 0.69 3.04 0.69 3.04

STRU 147 EQUI 17 Boiler #3 PM ‐ Total PM ‐ Total 0.3657 10e6 scf NatGas 10e6scf/hr 3,204 10e6 scf NatGas 10e6 scf/yr 7.60E+00 lb/10e6 scf [018] No 0% 2.78 12.17 2.78 12.17

STRU 147 EQUI 17 Boiler #3 PM10 (filterable) PM10 (filterable) 0.3657 10e6 scf NatGas 10e6scf/hr 3,204 10e6 scf NatGas 10e6 scf/yr 1.90E+00 lb/10e6 scf [017] No 0% 0.69 3.04 0.69 3.04

STRU 147 EQUI 17 Boiler #3 PM10 ‐ Total PM10 0.3657 10e6 scf NatGas 10e6scf/hr 3,204 10e6 scf NatGas 10e6 scf/yr 7.60E+00 lb/10e6 scf [018] No 0% 2.78 12.17 2.78 12.17

STRU 147 EQUI 17 Boiler #3 PM2.5 (filterable) PM2.5 (filterable) 0.3657 10e6 scf NatGas 10e6scf/hr 3,204 10e6 scf NatGas 10e6 scf/yr 1.90E+00 lb/10e6 scf [017] No 0% 0.69 3.04 0.69 3.04

STRU 147 EQUI 17 Boiler #3 PM2.5 ‐ Total PM2.5 0.3657 10e6 scf NatGas 10e6scf/hr 3,204 10e6 scf NatGas 10e6 scf/yr 7.60E+00 lb/10e6 scf [018] No 0% 2.78 12.17 2.78 12.17

STRU 147 EQUI 17 Boiler #3 Sulfur Dioxide SO2 0.3657 10e6 scf NatGas 10e6scf/hr 3,204 10e6 scf NatGas 10e6 scf/yr 6.00E‐01 lb/10e6 scf [017] No 0% 2.19E‐01 9.61E‐01 2.19E‐01 9.61E‐01

STRU 147 EQUI 17 Boiler #3 VOC as C VOC 373 MMBtu MMBtu/Hr 3,267,480 MMBtu MMBtu/year 9.00E‐03 lb/MMBtu [022] No 0% 3.36E+00 1.47E+01 3.36E+00 1.47E+01

STRU 147 EQUI 17 Boiler #3 Carbon Monoxide CO 373 MMBtu MMBtu/Hr 3,267,480 MMBtu MMBtu/year 9.00E‐02 lb/MMBtu [022] No 0% 33.57 147.04 33.57 147.04

STRU 147 EQUI 17 Boiler #3 PAH ‐ Total PAH ‐ Total 0.3657 10e6 scf NatGas 10e6scf/hr 3,204 10e6 scf NatGas 10e6 scf/yr 1.76E‐05 lb/e3 scf [043] No 0% 6.44E‐03 2.82E‐02 6.44E‐03 2.82E‐02

SV 450 EU 450 Boiler 8 REMOVED FROM PERMIT

NA

STRU 30 EQUI 18 Boiler # 9 Arsenic HAP 0.2010 10e6 scf NatGas 10e6scf/hr 1,761 10e6 scf NatGas 10e6 scf/yr 2.20E‐04 lb/10e6 scf [017] No 0% 4.42E‐05 1.94E‐04 4.42E‐05 1.94E‐04

STRU 30 EQUI 18 Boiler # 9 Benzene HAP 0.2010 10e6 scf NatGas 10e6scf/hr 1,761 10e6 scf NatGas 10e6 scf/yr 2.10E‐03 lb/10e6 scf [017] No 0% 4.22E‐04 1.85E‐03 4.22E‐04 1.85E‐03

STRU 30 EQUI 18 Boiler # 9 Cadmium HAP 0.2010 10e6 scf NatGas 10e6scf/hr 1,761 10e6 scf NatGas 10e6 scf/yr 1.10E‐03 lb/10e6 scf [017] No 0% 2.21E‐04 9.68E‐04 2.21E‐04 9.68E‐04

STRU 30 EQUI 18 Boiler # 9 Chromium HAP 0.2010 10e6 scf NatGas 10e6scf/hr 1,761 10e6 scf NatGas 10e6 scf/yr 1.40E‐03 lb/10e6 scf [017] No 0% 2.81E‐04 1.23E‐03 2.81E‐04 1.23E‐03

STRU 30 EQUI 18 Boiler # 9 Cobalt HAP 0.2010 10e6 scf NatGas 10e6scf/hr 1,761 10e6 scf NatGas 10e6 scf/yr 8.40E‐05 lb/10e6 scf [017] No 0% 1.69E‐05 7.40E‐05 1.69E‐05 7.40E‐05

STRU 30 EQUI 18 Boiler # 9 Formaldehyde HAP 0.2010 10e6 scf NatGas 10e6scf/hr 1,761 10e6 scf NatGas 10e6 scf/yr 7.50E‐02 lb/10e6 scf [017] No 0% 1.51E‐02 6.60E‐02 1.51E‐02 6.60E‐02

STRU 30 EQUI 18 Boiler # 9 Lead HAP 0.2010 10e6 scf NatGas 10e6scf/hr 1,761 10e6 scf NatGas 10e6 scf/yr 5.00E‐04 lb/10e6 scf [017] No 0% 1.01E‐04 4.40E‐04 1.01E‐04 4.40E‐04

STRU 30 EQUI 18 Boiler # 9 Mercury HAP 0.2010 10e6 scf NatGas 10e6scf/hr 1,761 10e6 scf NatGas 10e6 scf/yr 2.60E‐04 lb/10e6 scf [017] No 0% 5.23E‐05 2.29E‐04 5.23E‐05 2.29E‐04

STRU 30 EQUI 18 Boiler # 9 Naphthalene HAP 0.2010 10e6 scf NatGas 10e6scf/hr 1,761 10e6 scf NatGas 10e6 scf/yr 6.10E‐04 lb/10e6 scf [017] No 0% 1.23E‐04 5.37E‐04 1.23E‐04 5.37E‐04

STRU 30 EQUI 18 Boiler # 9 n‐Hexane HAP 0.2010 10e6 scf NatGas 10e6scf/hr 1,761 10e6 scf NatGas 10e6 scf/yr 1.80E+00 lb/10e6 scf [017] No 0% 3.62E‐01 1.58E+00 3.62E‐01 1.58E+00

STRU 30 EQUI 18 Boiler # 9 Nickel HAP 0.2010 10e6 scf NatGas 10e6scf/hr 1,761 10e6 scf NatGas 10e6 scf/yr 2.10E‐03 lb/10e6 scf [017] No 0% 4.22E‐04 1.85E‐03 4.22E‐04 1.85E‐03

STRU 30 EQUI 18 Boiler # 9 Selenium HAP 0.2010 10e6 scf NatGas 10e6scf/hr 1,761 10e6 scf NatGas 10e6 scf/yr 2.40E‐05 lb/10e6 scf [017] No 0% 4.82E‐06 2.11E‐05 4.82E‐06 2.11E‐05

STRU 30 EQUI 18 Boiler # 9 Toluene HAP 0.2010 10e6 scf NatGas 10e6scf/hr 1,761 10e6 scf NatGas 10e6 scf/yr 3.40E‐03 lb/10e6 scf [017] No 0% 6.83E‐04 2.99E‐03 6.83E‐04 2.99E‐03








Emissions [1]

STRU 30 EQUI 18 Boiler # 9 Nitrogen Oxides NOx 205 MMBtu MMBtu/Hr 1,795,800 MMBtu MMBtu/year 5.00E‐02 lbs/million Btu heat input

[022] No 0% 1.03E+01 4.49E+01 1.03E+01 4.49E+01

STRU 30 EQUI 18 Boiler # 9 PM (Condensable) PM (Condensable) 0.2010 10e6 scf NatGas 10e6scf/hr 1,761 10e6 scf NatGas 10e6 scf/yr 5.70E+00 lb/10e6 scf [018] No 0% 1.15 5.02 1.15 5.02

STRU 30 EQUI 18 Boiler # 9 PM (filterable) PM (filterable) 0.2010 10e6 scf NatGas 10e6scf/hr 1,761 10e6 scf NatGas 10e6 scf/yr 1.90E+00 lb/10e6 scf [017] No 0% 0.38 1.67 0.38 1.67

STRU 30 EQUI 18 Boiler # 9 PM ‐ Total PM ‐ Total 0.2010 10e6 scf NatGas 10e6scf/hr 1,761 10e6 scf NatGas 10e6 scf/yr 7.60E+00 lb/10e6 scf [018] No 0% 1.53 6.69 1.53 6.69

STRU 30 EQUI 18 Boiler # 9 PM10 (filterable) PM10 (filterable) 0.2010 10e6 scf NatGas 10e6scf/hr 1,761 10e6 scf NatGas 10e6 scf/yr 1.90E+00 lb/10e6 scf [017] No 0% 0.38 1.67 0.38 1.67

STRU 30 EQUI 18 Boiler # 9 PM10 ‐ Total PM10 0.2010 10e6 scf NatGas 10e6scf/hr 1,761 10e6 scf NatGas 10e6 scf/yr 7.60E+00 lb/10e6 scf [018] No 0% 1.53 6.69 1.53 6.69

STRU 30 EQUI 18 Boiler # 9 PM2.5 (filterable) PM2.5 (filterable) 0.2010 10e6 scf NatGas 10e6scf/hr 1,761 10e6 scf NatGas 10e6 scf/yr 1.90E+00 lb/10e6 scf [017] No 0% 0.38 1.67 0.38 1.67

STRU 30 EQUI 18 Boiler # 9 PM2.5 ‐ Total PM2.5 0.2010 10e6 scf NatGas 10e6scf/hr 1,761 10e6 scf NatGas 10e6 scf/yr 7.60E+00 lb/10e6 scf [018] No 0% 1.53 6.69 1.53 6.69

STRU 30 EQUI 18 Boiler # 9 Sulfur Dioxide SO2 0.2010 10e6 scf NatGas 10e6scf/hr 1,761 10e6 scf NatGas 10e6 scf/yr 6.00E‐01 lb/10e6 scf [017] No 0% 1.21E‐01 5.28E‐01 1.21E‐01 5.28E‐01

STRU 30 EQUI 18 Boiler # 9 VOC as C VOC 205 MMBtu MMBtu/Hr 1,795,800 MMBtu MMBtu/year 9.00E‐03 lb/MMBtu [022] No 0% 1.85E+00 8.08E+00 1.85E+00 8.08E+00

STRU 30 EQUI 18 Boiler # 9 Carbon Monoxide CO 3.36E+01 lb/hr [019] No 0% 33.60 147.17 33.60 147.17

STRU 30 EQUI 18 Boiler # 9 PAH ‐ Total PAH ‐ Total 0.2010 10e6 scf NatGas 10e6scf/hr 1,761 10e6 scf NatGas 10e6 scf/yr 1.76E‐05 lb/e3 scf [043] No 0% 3.54E‐03 1.55E‐02 3.54E‐03 1.55E‐02

STRU 31 EQUI 19 No. 2 Paper Machine 1,2,4‐Trichlorobenzene HAP 14 ADTFP Ton/Hr 122,640 ADTFP ton/year 1.78E‐03 lb/ADTFP [028] No 0% 2.49E‐02 1.09E‐01 2.49E‐02 1.09E‐01

STRU 31 EQUI 19 No. 2 Paper Machine Acetaldehyde HAP 14 ADTFP Ton/Hr 122,640 ADTFP ton/year 4.05E‐03 lb/ADTFP [028] No 0% 5.67E‐02 2.48E‐01 5.67E‐02 2.48E‐01

STRU 31 EQUI 19 No. 2 Paper Machine Acrolein HAP 14 ADTFP Ton/Hr 122,640 ADTFP ton/year 1.80E‐03 lb/ADTFP [028] No 0% 2.52E‐02 1.10E‐01 2.52E‐02 1.10E‐01

STRU 31 EQUI 19 No. 2 Paper Machine Benzene HAP 14 ADTFP Ton/Hr 122,640 ADTFP ton/year 2.25E‐04 lb/ADTFP [028] No 0% 3.15E‐03 1.38E‐02 3.15E‐03 1.38E‐02

STRU 31 EQUI 19 No. 2 Paper Machine Carbon Disulfide HAP 14 ADTFP Ton/Hr 122,640 ADTFP ton/year 7.37E‐04 lb/ADTFP [028] No 0% 1.03E‐02 4.52E‐02 1.03E‐02 4.52E‐02

STRU 31 EQUI 19 No. 2 Paper Machine Chlorobenzene HAP 14 ADTFP Ton/Hr 122,640 ADTFP ton/year 1.16E‐04 lb/ADTFP [028] No 0% 1.62E‐03 7.11E‐03 1.62E‐03 7.11E‐03

STRU 31 EQUI 19 No. 2 Paper Machine Chloroform HAP 14 ADTFP Ton/Hr 122,640 ADTFP ton/year 1.59E‐04 lb/ADTFP [028] No 0% 2.23E‐03 9.75E‐03 2.23E‐03 9.75E‐03

STRU 31 EQUI 19 No. 2 Paper Machine Ethyl Benzene HAP 14 ADTFP Ton/Hr 122,640 ADTFP ton/year 4.82E‐06 lb/ADTFP [028] No 0% 6.75E‐05 2.96E‐04 6.75E‐05 2.96E‐04

STRU 31 EQUI 19 No. 2 Paper Machine Formaldehyde HAP 14 ADTFP Ton/Hr 122,640 ADTFP ton/year 2.30E‐03 lb/ADTFP [028] No 0% 3.22E‐02 1.41E‐01 3.22E‐02 1.41E‐01

STRU 31 EQUI 19 No. 2 Paper Machine m,p‐Xylene HAP 14 ADTFP Ton/Hr 122,640 ADTFP ton/year 9.00E‐04 lb/ADTFP [028] No 0% 1.26E‐02 5.52E‐02 1.26E‐02 5.52E‐02

STRU 31 EQUI 19 No. 2 Paper Machine Methanol HAP 14 ADTFP Ton/Hr 122,640 ADTFP ton/year 3.91E‐02 lb/ADTFP [028] No 0% 5.47E‐01 2.40E+00 5.47E‐01 2.40E+00

STRU 31 EQUI 19 No. 2 Paper Machine Methyl Isobutyl Ketone HAP 14 ADTFP Ton/Hr 122,640 ADTFP ton/year 3.60E‐04 lb/ADTFP [028] No 0% 5.04E‐03 2.21E‐02 5.04E‐03 2.21E‐02

STRU 31 EQUI 19 No. 2 Paper Machine Methylene Chloride HAP 14 ADTFP Ton/Hr 122,640 ADTFP ton/year 1.81E‐03 lb/ADTFP [028] No 0% 2.53E‐02 1.11E‐01 2.53E‐02 1.11E‐01

STRU 31 EQUI 19 No. 2 Paper Machine Naphthalene HAP 14 ADTFP Ton/Hr 122,640 ADTFP ton/year 4.20E‐04 lb/ADTFP [028] No 0% 5.88E‐03 2.58E‐02 5.88E‐03 2.58E‐02

STRU 31 EQUI 19 No. 2 Paper Machine n‐Hexane HAP 14 ADTFP Ton/Hr 122,640 ADTFP ton/year 2.23E‐04 lb/ADTFP [028] No 0% 3.12E‐03 1.37E‐02 3.12E‐03 1.37E‐02

STRU 31 EQUI 19 No. 2 Paper Machine o‐Xylene HAP 14 ADTFP Ton/Hr 122,640 ADTFP ton/year 1.39E‐03 lb/ADTFP [028] No 0% 1.95E‐02 8.52E‐02 1.95E‐02 8.52E‐02

STRU 31 EQUI 19 No. 2 Paper Machine Phenol HAP 14 ADTFP Ton/Hr 122,640 ADTFP ton/year 7.35E‐03 lb/ADTFP [028] No 0% 1.03E‐01 4.51E‐01 1.03E‐01 4.51E‐01

STRU 31 EQUI 19 No. 2 Paper Machine Propionaldehyde HAP 14 ADTFP Ton/Hr 122,640 ADTFP ton/year 7.44E‐03 lb/ADTFP [028] No 0% 1.04E‐01 4.56E‐01 1.04E‐01 4.56E‐01

STRU 31 EQUI 19 No. 2 Paper Machine Styrene HAP 14 ADTFP Ton/Hr 122,640 ADTFP ton/year 3.28E‐04 lb/ADTFP [028] No 0% 4.59E‐03 2.01E‐02 4.59E‐03 2.01E‐02

STRU 31 EQUI 19 No. 2 Paper Machine Tetrachloroethylene HAP 14 ADTFP Ton/Hr 122,640 ADTFP ton/year 5.10E‐04 lb/ADTFP [028] No 0% 7.14E‐03 3.13E‐02 7.14E‐03 3.13E‐02

STRU 31 EQUI 19 No. 2 Paper Machine Toluene HAP 14 ADTFP Ton/Hr 122,640 ADTFP ton/year 1.59E‐04 lb/ADTFP [028] No 0% 2.23E‐03 9.75E‐03 2.23E‐03 9.75E‐03

STRU 31 EQUI 19 No. 2 Paper Machine Trichloroethylene HAP 14 ADTFP Ton/Hr 122,640 ADTFP ton/year 2.97E‐07 lb/ADTFP [028] No 0% 4.16E‐06 1.82E‐05 4.16E‐06 1.82E‐05

STRU 31 EQUI 19 No. 2 Paper Machine Xylenes (mixed isomers)

HAP 14 ADTFP Ton/Hr 122,640 ADTFP ton/year 1.55E‐04 lb/ADTFP [028] No 0% 2.17E‐03 9.50E‐03 2.17E‐03 9.50E‐03








Emissions [1]

STRU 31 EQUI 19 No. 2 Paper Machine PM (filterable) PM (filterable) 14 Paper Ton/Hr 122,640 Paper ton/year 1.01E‐02 lb/ADTFP [029] No 0% 1.41E‐01 6.17E‐01 1.41E‐01 6.17E‐01

STRU 31 EQUI 19 No. 2 Paper Machine PM10 (filterable) PM10 (filterable) 14 Paper Ton/Hr 122,640 Paper ton/year 6.15E‐03 lb/ADTFP [029] No 0% 8.61E‐02 3.77E‐01 8.61E‐02 3.77E‐01

STRU 31 EQUI 19 No. 2 Paper Machine PM2.5 (filterable) PM2.5 (filterable) 14 Paper Ton/Hr 122,640 Paper ton/year 2.74E‐03 lb/ADTFP [029] No 0% 3.84E‐02 1.68E‐01 3.84E‐02 1.68E‐01

STRU 31 EQUI 19 No. 2 Paper Machine PM (Condensable) PM (Condensable) 14 Paper Ton/Hr 122,640 Paper ton/year 3.59E‐02 lb/ADTFP [029] No 0% 5.02E‐01 2.20E+00 5.02E‐01 2.20E+00

STRU 31 EQUI 19 No. 2 Paper Machine PM ‐ TOTAL PM ‐ Total 14 Paper Ton/Hr 122,640 Paper ton/year 4.59E‐02 lb/ADTFP [029] No 0% 6.43E‐01 2.82E+00 6.43E‐01 2.82E+00

STRU 31 EQUI 19 No. 2 Paper Machine PM10 ‐ Total PM10 14 Paper Ton/Hr 122,640 Paper ton/year 4.20E‐02 lb/ADTFP [029] No 0% 5.88E‐01 2.58E+00 5.88E‐01 2.58E+00

STRU 31 EQUI 19 No. 2 Paper Machine PM2.5 ‐ Total PM2.5 14 Paper Ton/Hr 122,640 Paper ton/year 3.86E‐02 lb/ADTFP [029] No 0% 5.40E‐01 2.37E+00 5.40E‐01 2.37E+00

STRU 31 EQUI 19 No. 2 Paper Machine Volatile Organic Compounds

VOC 14 ADTFP Ton/Hr 122,640 ADTFP ton/year 0.07 lb/ADTFP [028] No 0% 9.66E‐01 4.23E+00 9.66E‐01 4.23E+00


STRU 35 EQUI 20 No. 3 Paper Machine Acetaldehyde HAP 20 ADTFP Ton/Hr 175,200 ADTFP ton/year 4.05E‐03 lb/ADTFP [028] No 0% 8.10E‐02 3.55E‐01 8.10E‐02 3.55E‐01





STRU 35 EQUI 20 No. 3 Paper Machine Chloroform HAP 20 ADTFP Ton/Hr 175,200 ADTFP ton/year 1.30E‐02 lb/ADTFP [028] No 0% 2.60E‐01 1.14E+00 2.60E‐01 1.14E+00


STRU 35 EQUI 20 No. 3 Paper Machine Formaldehyde HAP 20 ADTFP Ton/Hr 175,200 ADTFP ton/year 2.30E‐03 lb/ADTFP [028] No 0% 4.60E‐02 2.01E‐01 4.60E‐02 2.01E‐01


STRU 35 EQUI 20 No. 3 Paper Machine Methanol HAP 20 ADTFP Ton/Hr 175,200 ADTFP ton/year 3.91E‐02 lb/ADTFP [028] No 0% 7.82E‐01 3.43E+00 7.82E‐01 3.43E+00














STRU 35 EQUI 20 No. 3 Paper Machine PM (filterable) PM (filterable) 20 Paper Ton/Hr 175,200 Paper ton/year 1.13E‐02 lb/ADTFP [029] No 0% 2.27E‐01 9.92E‐01 2.27E‐01 9.92E‐01











Emissions [1]





VOC 20 ADTFP Ton/Hr 175,200 ADTFP ton/year 0.07 lb/ADTFP [028] No 0% 1.38E+00 6.04E+00 1.38E+00 6.04E+00


STRU 88 EQUI 21 No. 4 Paper Machine Acetaldehyde HAP 15 ADTFP Ton/Hr 131,400 ADTFP ton/year 7.70E‐02 lb/ADTFP [028] No 0% 1.16E+00 5.06E+00 1.16E+00 5.06E+00





STRU 88 EQUI 21 No. 4 Paper Machine Chloroform HAP 15 ADTFP Ton/Hr 131,400 ADTFP ton/year 1.20E‐02 lb/ADTFP [028] No 0% 1.80E‐01 7.88E‐01 1.80E‐01 7.88E‐01


STRU 88 EQUI 21 No. 4 Paper Machine Formaldehyde HAP 15 ADTFP Ton/Hr 131,400 ADTFP ton/year 2.20E‐02 lb/ADTFP [028] No 0% 3.30E‐01 1.45E+00 3.30E‐01 1.45E+00


STRU 88 EQUI 21 No. 4 Paper Machine Methanol HAP 15 ADTFP Ton/Hr 131,400 ADTFP ton/year 1.21E+00 lb/ADTFP [028] No 0% 1.82E+01 7.95E+01 1.82E+01 7.95E+01














STRU 88 EQUI 21 No. 4 Paper Machine PM (filterable) PM (filterable) 15 Paper Ton/Hr 131,400 Paper ton/year 1.76E‐02 lb/ADTFP [029] No 0% 2.63E‐01 1.15E+00 2.63E‐01 1.15E+00
















Emissions [1]


STRU 96 EQUI 22 No. 1 Paper Machine Acetaldehyde HAP 60 ADTFP Ton/Hr 525,600 ADTFP ton/year 2.60E‐02 lb/ADTFP [028] No 0% 1.56E+00 6.83E+00 1.56E+00 6.83E+00





STRU 96 EQUI 22 No. 1 Paper Machine Chloroform HAP 60 ADTFP Ton/Hr 525,600 ADTFP ton/year 8.59E‐03 lb/ADTFP [028] No 0% 5.15E‐01 2.26E+00 5.15E‐01 2.26E+00


STRU 96 EQUI 22 No. 1 Paper Machine Formaldehyde HAP 60 ADTFP Ton/Hr 525,600 ADTFP ton/year 4.21E‐03 lb/ADTFP [028] No 0% 2.53E‐01 1.11E+00 2.53E‐01 1.11E+00


STRU 96 EQUI 22 No. 1 Paper Machine Methanol HAP 60 ADTFP Ton/Hr 525,600 ADTFP ton/year 3.91E‐02 lb/ADTFP [028] No 0% 2.35E+00 1.03E+01 2.35E+00 1.03E+01

STRU 96 EQUI 22 No. 1 Paper Machine Methyl Isobutyl Ketone HAP 60 ADTFP Ton/Hr 525,600 ADTFP ton/year 1.20E‐02 lb/ADTFP [028] No 0% 7.20E‐01 3.15E+00 7.20E‐01 3.15E+00





STRU 96 EQUI 22 No. 1 Paper Machine Phenol HAP 60 ADTFP Ton/Hr 525,600 ADTFP ton/year 7.35E‐03 lb/ADTFP [028] No 0% 4.41E‐01 1.93E+00 4.41E‐01 1.93E+00

STRU 96 EQUI 22 No. 1 Paper Machine Propionaldehyde HAP 60 ADTFP Ton/Hr 525,600 ADTFP ton/year 7.44E‐03 lb/ADTFP [028] No 0% 4.46E‐01 1.96E+00 4.46E‐01 1.96E+00







STRU 96 EQUI 22 No. 1 Paper Machine PM (filterable) PM (filterable) 60 Paper Ton/Hr 525,600 Paper ton/year 2.80E‐02 lb/ADTFP [029] No 0% 1.68E+00 7.35E+00 1.68E+00 7.35E+00

STRU 96 EQUI 22 No. 1 Paper Machine PM10 (filterable) PM10 (filterable) 60 Paper Ton/Hr 525,600 Paper ton/year 1.81E‐02 lb/ADTFP [029] No 0% 1.08E+00 4.75E+00 1.08E+00 4.75E+00

STRU 96 EQUI 22 No. 1 Paper Machine PM2.5 (filterable) PM2.5 (filterable) 60 Paper Ton/Hr 525,600 Paper ton/year 6.81E‐03 lb/ADTFP [029] No 0% 4.09E‐01 1.79E+00 4.09E‐01 1.79E+00

STRU 96 EQUI 22 No. 1 Paper Machine PM (Condensable) PM (Condensable) 60 Paper Ton/Hr 525,600 Paper ton/year 3.13E‐02 lb/ADTFP [029] No 0% 1.88E+00 8.22E+00 1.88E+00 8.22E+00

STRU 96 EQUI 22 No. 1 Paper Machine PM ‐ TOTAL PM ‐ Total 60 Paper Ton/Hr 525,600 Paper ton/year 5.92E‐02 lb/ADTFP [029] No 0% 3.55E+00 1.56E+01 3.55E+00 1.56E+01

STRU 96 EQUI 22 No. 1 Paper Machine PM10 ‐ Total PM10 60 Paper Ton/Hr 525,600 Paper ton/year 4.93E‐02 lb/ADTFP [029] No 0% 2.96E+00 1.30E+01 2.96E+00 1.30E+01

STRU 96 EQUI 22 No. 1 Paper Machine PM2.5 ‐ Total PM2.5 60 Paper Ton/Hr 525,600 Paper ton/year 3.81E‐02 lb/ADTFP [029] No 0% 2.29E+00 1.00E+01 2.29E+00 1.00E+01



STRU 72 EQUI 944 Wastewater Treatment Plant Cooling Tower

Chloroform HAP 32 Water Mgal/Day 1,700 Water Mgal/year 9.20E‐01 lb/MG [030] No 0% 1.23E+00 0.78 1.23E+00 0.78


Methanol HAP 32 Water Mgal/Day 1,700 Water Mgal/year 5.18E+00 lb/MG [030] No 0% 6.90E+00 4.40 6.90E+00 4.40


Sulfur ‐ Total Reduced TRS 32 Water Mgal/Day 1,700 Water Mgal/year 3.42E+00 lb/MG [030] No 0% 4.56E+00 2.91 4.56E+00 2.91


PM ‐ TOTAL PM ‐ Total 32 Water Mgal/Day 1,700 Water Mgal/year 1.67E+01 lb/MG [045] No 0% 2.22E+01 14.18 2.22E+01 14.18








Emissions [1]


PM10 ‐ Total PM10 32 Water Mgal/Day 1,700 Water Mgal/year 1.67E+01 lb/MG [045] No 0% 2.22E+01 14.18 2.22E+01 14.18


PM2.5 ‐ Total PM2.5 32 Water Mgal/Day 1,700 Water Mgal/year 1.67E+01 lf/MG [045] No 0% 2.22E+01 14.18 2.22E+01 14.18


Volatile Organic Compounds

VOC 32 Water Mgal/Day 1,700 Water Mgal/year 21.98 lb/MG [030] No 0% 29.30 18.68 29.30 18.68

STRU 74 EQUI 12 Paint Spray Booth Ethylbenzene HAP 24 Hours Hours/day 1,044 Hours Hours/Year 1.81 lb/hr [031] No 0% 1.81E+00 0.94 1.81E+00 0.94

STRU 74 EQUI 12 Paint Spray Booth Toluene HAP 24 Hours Hours/day 1,044 Hours Hours/Year 2.26 lb/hr [031] No 0% 2.26E+00 1.18 2.26E+00 1.18

STRU 74 EQUI 12 Paint Spray Booth Xylenes (mixed isomers)

HAP 24 Hours Hours/day 1,044 Hours Hours/Year 8.55 lb/hr [031] No 0% 8.55E+00 4.46 8.55E+00 4.46

STRU 74 EQUI 12 Paint Spray Booth Volatile Organic Compounds

VOC 24 Hours Hours/day 1,044 Hours Hours/Year 22.5 lb/hr [031] No 0% 2.25E+01 11.75 2.25E+01 11.75

STRU 74 EQUI 12 Paint Spray Booth PM (Condensable) PM (Condensable) 24 Hours Hours/day 1,044 Hours Hours/Year 9.70E‐01 lb/hr [048] No 0% 9.70E‐01 0.51 9.70E‐01 0.51

STRU 74 EQUI 12 Paint Spray Booth PM < 2.5 micron ‐ TOTAL

PM2.5 24 Hours Hours/day 1,044 Hours Hours/Year 9.70E‐01 [048] No 0% 0.97 0.51 0.97 0.51

STRU 74 EQUI 12 Paint Spray Booth PM < 10 micron ‐ TOTAL

PM10 24 Hours Hours/day 1,044 Hours Hours/Year 9.70E‐01 [048] No 0% 0.97 0.51 0.97 0.51

STRU 74 EQUI 12 Paint Spray Booth PM ‐ TOTAL PM ‐ Total 24 Hours Hours/day 1,044 Hours Hours/Year 9.70E‐01 [048] No 0% 0.97 0.51 0.97 0.51

STRU 76 EQUI 24 Sludge Dryer PM < 2.5 micron PM2.5 30 Sludge BDT/Day 10,950 Sludge BDT/year 5.20E‐01 lb/BDT [032] No 0% 6.50E‐01 2.85E+00 6.50E‐01 2.85E+00

STRU 76 EQUI 24 Sludge Dryer PM < 10 micron PM10 30 Sludge BDT/Day 10,950 Sludge BDT/year 5.20E‐01 lb/BDT [032] No 0% 6.50E‐01 2.85E+00 6.50E‐01 2.85E+00

STRU 76 EQUI 24 Sludge Dryer Total Particulate Matter

PM ‐ Total 30 Sludge BDT/Day 10,950 Sludge BDT/year 5.20E‐01 lb/BDT [032] No 0% 6.50E‐01 2.85E+00 6.50E‐01 2.85E+00

STRU 76 EQUI 24 Sludge Dryer Sulfur ‐ Total Reduced TRS 30 Sludge BDT/Day 10,950 Sludge BDT/year 8.32E‐02 lb/BDT [032] No 0% 1.04E‐01 4.56E‐01 1.04E‐01 4.56E‐01

STRU 76 EQUI 24 Sludge Dryer Volatile Organic Compounds

VOC 30 Sludge BDT/Day 10,950 Sludge BDT/year 2.80E+00 lb/BDT [032] No 0% 3.50E+00 1.53E+01 3.50E+00 1.53E+01

STRU 108 EQUI 52UNOX Vent (A)

VOC VOC 63 ADTUP/vent Vent 547,500 ADTUP/vent Vent 2.58E‐02 lb/ADT/vent [054] No 0% 1.61E+00 7.07E+00 1.61E+00 7.07E+00


Acrolein HAP 63 ADTUP/vent Vent 547,500 ADTUP/vent Vent 9.22E‐07 lb/ADT/vent [055] No 0% 5.76E‐05 2.52E‐04 5.76E‐05 2.52E‐04


Chlorobenzene HAP 63 ADTUP/vent Vent 547,500 ADTUP/vent Vent 2.44E‐06 lb/ADT/vent [055] No 0% 1.53E‐04 6.69E‐04 1.53E‐04 6.69E‐04


Chloroform HAP 63 ADTUP/vent Vent 547,500 ADTUP/vent Vent 2.11E‐04 lb/ADT/vent [055] No 0% 1.32E‐02 5.78E‐02 1.32E‐02 5.78E‐02


Methanol HAP 63 ADTUP/vent Vent 547,500 ADTUP/vent Vent 1.33E‐06 lb/ADT/vent [055] No 0% 8.33E‐05 3.65E‐04 8.33E‐05 3.65E‐04


Methyl Ethyl Ketone HAP 63 ADTUP/vent Vent 547,500 ADTUP/vent Vent 5.67E‐07 lb/ADT/vent [055] No 0% 3.54E‐05 1.55E‐04 3.54E‐05 1.55E‐04


Methyl Isobuty Ketone HAP 63 ADTUP/vent Vent 547,500 ADTUP/vent Vent 2.78E‐07 lb/ADT/vent [055] No 0% 1.74E‐05 7.60E‐05 1.74E‐05 7.60E‐05


Styrene HAP 63 ADTUP/vent Vent 547,500 ADTUP/vent Vent 6.22E‐06 lb/ADT/vent [055] No 0% 3.89E‐04 1.70E‐03 3.89E‐04 1.70E‐03


Terpenes HAP 63 ADTUP/vent Vent 547,500 ADTUP/vent Vent 6.00E‐04 lb/ADT/vent [055] No 0% 3.75E‐02 1.64E‐01 3.75E‐02 1.64E‐01


Toluene HAP 63 ADTUP/vent Vent 547,500 ADTUP/vent Vent 2.44E‐06 lb/ADT/vent [055] No 0% 1.53E‐04 6.69E‐04 1.53E‐04 6.69E‐04


1,2,4‐Trichlorobenzene HAP 63 ADTUP/vent Vent 547,500 ADTUP/vent Vent 7.67E‐07 lb/ADT/vent [055] No 0% 4.79E‐05 2.10E‐04 4.79E‐05 2.10E‐04


Xylenes HAP 63 ADTUP/vent Vent 547,500 ADTUP/vent Vent 1.12E‐06 lb/ADT/vent [055] No 0% 7.01E‐05 3.07E‐04 7.01E‐05 3.07E‐04

STRU 109 EQUI 53UNOX Vent (B)

VOCs as C VOC 63 ADTUP/vent Vent 547,500 ADTUP/vent Vent 2.58E‐02 lb/ADT/vent [054] No 0% 1.61E+00 7.07E+00 1.61E+00 7.07E+00


Acrolein HAP 63 ADTUP/vent Vent 547,500 ADTUP/vent Vent 9.22E‐07 lb/ADT/vent [055] No 0% 5.76E‐05 2.52E‐04 5.76E‐05 2.52E‐04


Chlorobenzene HAP 63 ADTUP/vent Vent 547,500 ADTUP/vent Vent 2.44E‐06 lb/ADT/vent [055] No 0% 1.53E‐04 6.69E‐04 1.53E‐04 6.69E‐04


Chloroform HAP 63 ADTUP/vent Vent 547,500 ADTUP/vent Vent 2.11E‐04 lb/ADT/vent [055] No 0% 1.32E‐02 5.78E‐02 1.32E‐02 5.78E‐02


Methanol HAP 63 ADTUP/vent Vent 547,500 ADTUP/vent Vent 1.33E‐06 lb/ADT/vent [055] No 0% 8.33E‐05 3.65E‐04 8.33E‐05 3.65E‐04


Methyl Ethyl Ketone HAP 63 ADTUP/vent Vent 547,500 ADTUP/vent Vent 5.67E‐07 lb/ADT/vent [055] No 0% 3.54E‐05 1.55E‐04 3.54E‐05 1.55E‐04


Methyl Isobuty Ketone HAP 63 ADTUP/vent Vent 547,500 ADTUP/vent Vent 2.78E‐07 lb/ADT/vent [055] No 0% 1.74E‐05 7.60E‐05 1.74E‐05 7.60E‐05








Emissions [1]


Styrene HAP 63 ADTUP/vent Vent 547,500 ADTUP/vent Vent 6.22E‐06 lb/ADT/vent [055] No 0% 3.89E‐04 1.70E‐03 3.89E‐04 1.70E‐03


Terpenes HAP 63 ADTUP/vent Vent 547,500 ADTUP/vent Vent 6.00E‐04 lb/ADT/vent [055] No 0% 3.75E‐02 1.64E‐01 3.75E‐02 1.64E‐01


Toluene HAP 63 ADTUP/vent Vent 547,500 ADTUP/vent Vent 2.44E‐06 lb/ADT/vent [055] No 0% 1.53E‐04 6.69E‐04 1.53E‐04 6.69E‐04


1,2,4‐Trichlorobenzene HAP 63 ADTUP/vent Vent 547,500 ADTUP/vent Vent 7.67E‐07 lb/ADT/vent [055] No 0% 4.79E‐05 2.10E‐04 4.79E‐05 2.10E‐04


Xylenes HAP 63 ADTUP/vent Vent 547,500 ADTUP/vent Vent 1.12E‐06 lb/ADT/vent [055] No 0% 7.01E‐05 3.07E‐04 7.01E‐05 3.07E‐04

STRU 107 EQUI 25 Off‐Machine Coater Volatile Organic Compounds

VOC 7 Paper Ton/Hr 61,320 Paper ton/year 0.33 lb/ton paper [033] No 0% 2.31 10.12 2.31 10.12

STRU 82 EQUI 940 Intermediate Chip Booster Station

Total Particulate Matter

PM ‐ Total 24 hours hr/day 8,760 Hours Hours/Year 3.00E+00 lb/hr [042] No 0% 3.00E+00 13.14 3.00E+00 13.14


Particulate Matter < 10 micron

PM10 24 hours hr/day 8,760 Hours Hours/Year 2.90E+00 lb/hr [042] No 0% 2.90E+00 12.70 2.90E+00 12.70


Particulate Matter < 2.5 micron

PM2.5 24 hours hr/day 8,760 Hours Hours/Year 2.90E+00 lb/hr [042] No 0% 2.90E+00 12.70 2.90E+00 12.70

STRU 37 COMG 6 LVHC System ‐ Venting 1,2,4‐Trichlorobenzene HAP 1,500 ADTUBP ADT/Day 15 % of operating time ADTUBP/day(1% venting)

5.70E‐03 lb/ADTUBP [040] No 0% 3.56E‐03 1.56E‐02 3.56E‐03 1.56E‐02

STRU 37 COMG 6 LVHC System ‐ Venting Acetaldehyde HAP 1,500 ADTUBP ADT/Day 15 % of operating time ADTUBP/day(1% venting)


STRU 37 COMG 6 LVHC System ‐ Venting Acrolein HAP 1,500 ADTUBP ADT/Day 15 % of operating time ADTUBP/day(1% venting)


STRU 37 COMG 6 LVHC System ‐ Venting Benzene HAP 1,500 ADTUBP ADT/Day 15 % of operating time ADTUBP/day(1% venting)


STRU 37 COMG 6 LVHC System ‐ Venting Carbon Disulfide HAP 1,500 ADTUBP ADT/Day 15 % of operating time ADTUBP/day(1% venting)


STRU 37 COMG 6 LVHC System ‐ Venting Carbon Tetrachloride HAP 1,500 ADTUBP ADT/Day 15 % of operating time ADTUBP/day(1% venting)


STRU 37 COMG 6 LVHC System ‐ Venting Chlorobenzene HAP 1,500 ADTUBP ADT/Day 15 % of operating time ADTUBP/day(1% venting)


STRU 37 COMG 6 LVHC System ‐ Venting Chloroform HAP 1,500 ADTUBP ADT/Day 15 % of operating time ADTUBP/day(1% venting)


STRU 37 COMG 6 LVHC System ‐ Venting Cumene HAP 1,500 ADTUBP ADT/Day 15 % of operating time ADTUBP/day(1% venting)


STRU 37 COMG 6 LVHC System ‐ Venting Ethyl Benzene HAP 1,500 ADTUBP ADT/Day 15 % of operating time ADTUBP/day(1% venting)


STRU 37 COMG 6 LVHC System ‐ Venting Formaldehyde HAP 1,500 ADTUBP ADT/Day 15 % of operating time ADTUBP/day(1% venting)


STRU 37 COMG 6 LVHC System ‐ Venting m,p‐Xylene HAP 1,500 ADTUBP ADT/Day 15 % of operating time ADTUBP/day(1% venting)


STRU 37 COMG 6 LVHC System ‐ Venting Methanol HAP 1,500 ADTUBP ADT/Day 15 % of operating time ADTUBP/day(1% venting)


STRU 37 COMG 6 LVHC System ‐ Venting Methyl Isobutyl Ketone HAP 1,500 ADTUBP ADT/Day 15 % of operating time ADTUBP/day(1% venting)


STRU 37 COMG 6 LVHC System ‐ Venting n‐Hexane HAP 1,500 ADTUBP ADT/Day 15 % of operating time ADTUBP/day(1% venting)


STRU 37 COMG 6 LVHC System ‐ Venting o‐Xylene HAP 1,500 ADTUBP ADT/Day 15 % of operating time ADTUBP/day(1% venting)


STRU 37 COMG 6 LVHC System ‐ Venting Phenol HAP 1,500 ADTUBP ADT/Day 15 % of operating time ADTUBP/day(1% venting)


STRU 37 COMG 6 LVHC System ‐ Venting Styrene HAP 1,500 ADTUBP ADT/Day 15 % of operating time ADTUBP/day(1% venting)


STRU 37 COMG 6 LVHC System ‐ Venting Toluene HAP 1,500 ADTUBP ADT/Day 15 % of operating time ADTUBP/day(1% venting)


STRU 37 COMG 6 LVHC System ‐ Venting TRS as S TRS 1,500 ADTUBP ADT/Day 15 % of operating time ADTUBP/day(1% venting)

1.22E+00 lb/ADTUBP [040] No 0% 7.65E‐01 3.35E+00 7.65E‐01 3.35E+00

STRU 37 COMG 6 LVHC System ‐ Venting Xylenes (mixed isomers)

HAP 1,500 ADTUBP ADT/Day 15 % of operating time ADTUBP/day(1% venting)


STRU 37 COMG 6 LVHC System ‐ Venting VOCs as C VOC 1,500 ADTUBP ADT/Day 15 % of operating time ADTUBP/day(1% venting)

7.10E‐01 lb/ADTUBP [040] No 0% 4.44E‐01 1.94E+00 4.44E‐01 1.94E+00

STRU 37 COMG 6 LVHC System Incineration SO2 SO2 NA NA 1.15E+02 tons/year [046] NA 115.00

STRU 112 COMG 8 HVLC System ‐ Venting Acetaldehyde HAP 1,500 ADTUBP MACT limit 60 % of operating time ADTUBP/ay(4% venting)


STRU 112 COMG 8 HVLC System ‐ Venting Benzene HAP 1,500 ADTUBP MACT limit 60 % of operating time ADTUBP/ay(4% venting)


STRU 112 COMG 8 HVLC System ‐ Venting Carbon Tetrachloride HAP 1,500 ADTUBP MACT limit 60 % of operating time ADTUBP/ay(4% venting)









Emissions [1]

STRU 112 COMG 8 HVLC System ‐ Venting Methanol HAP 1,500 ADTUBP MACT limit 60 % of operating time ADTUBP/ay(4% venting)


STRU 112 COMG 8 HVLC System ‐ Venting Methyl Isobutyl Ketone HAP 1,500 ADTUBP MACT limit 60 % of operating time ADTUBP/ay(4% venting)


STRU 112 COMG 8 HVLC System ‐ Venting Methylene Chloride HAP 1,500 ADTUBP MACT limit 60 % of operating time ADTUBP/ay(4% venting)


STRU 112 COMG 8 HVLC System ‐ Venting Styrene HAP 1,500 ADTUBP MACT limit 60 % of operating time ADTUBP/ay(4% venting)


STRU 112 COMG 8 HVLC System ‐ Venting Toluene HAP 1,500 ADTUBP MACT limit 60 % of operating time ADTUBP/ay(4% venting)


STRU 112 COMG 8 HVLC System ‐ Venting TRS as S TRS 1,500 ADTUBP MACT limit 60 % of operating time ADTUBP/ay(4% venting)


STRU 112 COMG 8 HVLC System ‐ Venting Xylenes (mixed isomers)

HAP 1,500 ADTUBP MACT limit 60 % of operating time ADTUBP/ay(4% venting)




Engines

Emission Unit

ID Description Pollutant (lb/hr) (tons/yr)EQUI 941 Lime Kiln Aux. Engine Nox 35 hp 500 hr 2.64E‐02 lbs/hp‐hr 9.25E‐01 2.31E‐01

propane CO 35 hp 500 hr 6.22E‐02 lbs/hp‐hr 2.18E+00 5.45E‐01TPM 35 hp 500 hr 1.10E‐04 lbs/hp‐hr 3.86E‐03 9.65E‐04PM10 35 hp 500 hr 1.10E‐04 lbs/hp‐hr 3.86E‐03 9.65E‐04PM2.5 35 hp 500 hr 1.10E‐04 lbs/hp‐hr 3.86E‐03 9.65E‐04VOC 35 hp 500 hr 3.70E‐03 lbs/hp‐hr 1.30E‐01 3.24E‐02CO2 0.245 MMBtu/Hr 500 hr 1.39E+02 lb/MMBtu 3.40E+01 8.49E+00CH4 0.245 MMBtu/Hr 500 hr 6.62E‐03 lb/MMBtu 1.62E‐03 4.05E‐04N2O 0.245 MMBtu/Hr 500 hr 1.32E‐03 lb/MMBtu 3.24E‐04 8.10E‐05CO2e 3.41E+01 8.53E+00

EQUI 942 Fire Pump #3 Engine Nox 216 hp 500 hr 3.10E‐02 lbs/hp‐hr 6.70E+00 1.67E+00diesel CO 216 hp 500 hr 6.68E‐03 lbs/hp‐hr 1.44E+00 3.61E‐01

SO2 216 hp 500 hr 2.05E‐03 lbs/hp‐hr 4.43E‐01 1.11E‐01TPM 216 hp 500 hr 2.20E‐03 lbs/hp‐hr 4.75E‐01 1.19E‐01PM10 216 hp 500 hr 2.20E‐03 lbs/hp‐hr 4.75E‐01 1.19E‐01PM2.5 216 hp 500 hr 2.20E‐03 lbs/hp‐hr 4.75E‐01 1.19E‐01VOC 216 hp 500 hr 2.47E‐03 lbs/hp‐hr 5.34E‐01 1.33E‐01CO2 216 hp 500 hr 1.15E+00 lbs/hp‐hr 2.48E+02 6.21E+01CH4 1.512 MMBtu/Hr 500 hr 6.62E‐03 lb/MMBtu 1.00E‐02 2.50E‐03N2O 1.512 MMBtu/Hr 500 hr 1.32E‐03 lb/MMBtu 2.00E‐03 5.00E‐04CO2e 2.49E+02 6.23E+01

EQUI 943 Guard Standby Generator Nox 215 hp 500 hr 2.64E‐02 lbs/hp‐hr 5.68E+00 1.42E+00propane CO 215 hp 500 hr 6.22E‐02 lbs/hp‐hr 1.34E+01 3.35E+00

TPM 215 hp 500 hr 1.10E‐04 lbs/hp‐hr 2.37E‐02 5.93E‐03PM10 215 hp 500 hr 1.10E‐04 lbs/hp‐hr 2.37E‐02 5.93E‐03PM2.5 215 hp 500 hr 1.10E‐04 lbs/hp‐hr 2.37E‐02 5.93E‐03VOC 215 hp 500 hr 3.70E‐03 lbs/hp‐hr 7.96E‐01 1.99E‐01CO2 1.505 MMBtu/Hr 500 hr 1.39E+02 lb/MMBtu 2.09E+02 5.22E+01CH4 1.505 MMBtu/Hr 500 hr 6.62E‐03 lb/MMBtu 9.96E‐03 2.49E‐03N2O 1.505 MMBtu/Hr 500 hr 1.32E‐03 lb/MMBtu 1.99E‐03 4.98E‐04CO2e 2.09E+02 5.24E+01

Limited Potential Emissions [1]Emission factorThroughput Units

Annual Throughput

Units Units

Boise White Paper, LLC ‐ International Falls, MNPTE Calculations ‐ Fugitive Sources7/21/2014

Source Number Description Pollutant

Annual Max Daily Units Notes Factor Notes Ibs/hr tons/yearFS 001 (IA) Log Debarking 492,000 2,100 BDT tons debarked logs [02] PM 4.00E‐03 lbs/ton [12] 3.50E‐01 9.84E‐01FS 001 (IA) Log Debarking PM10 2.20E‐03 lbs/ton [12] 1.93E‐01 5.41E‐01FS 001 (IA) Log Debarking PM2.5 2.20E‐03 lbs/ton [12] 1.93E‐01 5.41E‐01FS 002 (IA) Bark Conveying 324,120 1,340 tons of bark [03] PM 5.67E‐05 lbs/ton [13] 3.16E‐03 9.18E‐03FS 002 (IA) Bark Conveying PM10 2.68E‐05 lbs/ton [13] 1.50E‐03 4.34E‐03FS 002 (IA) Bark Conveying PM2.5 4.06E‐06 lbs/ton [13] 2.27E‐04 6.58E‐04FS 003 (IA) Bark Pile at Process Center . 1 acres [04] PM ‐ Wind Erosion 2.98E+00 lbs/day/acre [14] 1.24E‐01 5.44E‐01FS 003 (IA) Bark Pile at Process Center PM10 ‐ Wind Erosion 1.49E+00 lbs/day/acre [14] 6.21E‐02 2.72E‐01FS 003 (IA) Bark Pile at Process Center PM2.5 ‐ Wind Erosion 2.24E‐01 lbs/day/acre [14] 9.31E‐03 4.08E‐02FS005 (IA) Bark Loader at Process Center 324,120 1,340 tons of bark [05] PM 5.67E‐05 lbs/ton [13] 3.16E‐03 9.18E‐03FS005 (IA) Bark Loader at Process Center PM10 2.68E‐05 lbs/ton [13] 1.50E‐03 4.34E‐03FS005 (IA) Bark Loader at Process Center PM2.5 4.06E‐06 lbs/ton [13] 2.27E‐04 6.58E‐04FS 008 (IA) Wood Chipping and Chip Conveying 1,640,000 7,000 tons of green chips [31] PM 1.54E‐04 lbs/ton [16] 4.49E‐02 1.26E‐01FS 008 (IA) Wood Chipping and Chip Conveying PM10 7.28E‐05 lbs/ton [16] 2.12E‐02 5.97E‐02FS 008 (IA) Wood Chipping and Chip Conveying PM2.5 1.10E‐05 lbs/ton [16] 3.22E‐03 9.04E‐03FS 009‐1 (IA) Wood Chip Pile 0.7 acres [32] PM 3.40E‐01 lbs/day/acre [14] 9.92E‐03 4.34E‐02FS 009‐1 (IA) Wind Erosion PM10 1.70E‐01 lbs/day/acre [14] 4.96E‐03 2.17E‐02FS 009‐1 (IA) PM2.5 2.55E‐02 lbs/day/acre [14] 7.44E‐04 3.26E‐03FS 009‐2 (IA) Wood Chip Pile 0.7 acres [32] PM 3.40E‐01 lbs/day/acre [14] 9.92E‐03 4.34E‐02FS 009‐2 (IA) Wind Erosion PM10 1.70E‐01 lbs/day/acre [14] 4.96E‐03 2.17E‐02FS 009‐2 (IA) PM2.5 2.55E‐02 lbs/day/acre [14] 7.44E‐04 3.26E‐03FS 009‐3 (IA) Wood Chip Pile 0.7 acres [32] PM 3.40E‐01 lbs/day/acre [14] 9.92E‐03 4.34E‐02FS 009‐3 (IA) Wind Erosion PM10 1.70E‐01 lbs/day/acre [14] 4.96E‐03 2.17E‐02FS 009‐3 (IA) PM2.5 2.55E‐02 lbs/day/acre [14] 7.44E‐04 3.26E‐03FS 009‐4 (IA) Wood Chip Pile 0.7 acres [32] PM 3.40E‐01 lbs/day/acre [14] 9.92E‐03 4.34E‐02FS 009‐4 (IA) Wind Erosion PM10 1.70E‐01 lbs/day/acre [14] 4.96E‐03 2.17E‐02FS 009‐4 (IA) PM2.5 2.55E‐02 lbs/day/acre [14] 7.44E‐04 3.26E‐03FS 009‐5 (IA) Wood Chip Pile 0.7 acres [32] PM 3.40E‐01 lbs/day/acre [14] 9.92E‐03 4.34E‐02FS 009‐5 (IA) Wind Erosion PM10 1.70E‐01 lbs/day/acre [14] 4.96E‐03 2.17E‐02FS 009‐5 (IA) PM2.5 2.55E‐02 lbs/day/acre [14] 7.44E‐04 3.26E‐03FS 009‐6 (IA) Wood Chip Pile 3 acres [32] PM 3.40E‐01 lbs/day/acre [14] 4.25E‐02 1.86E‐01FS 009‐6 (IA) Wind Erosion PM10 1.70E‐01 lbs/day/acre [14] 2.13E‐02 9.31E‐02FS 009‐6 (IA) PM2.5 2.55E‐02 lbs/day/acre [14] 3.19E‐03 1.40E‐02FS 009‐7 (IA) Wood Chip Pile 4 acres [32] PM 3.40E‐01 lbs/day/acre [14] 5.67E‐02 2.48E‐01FS 009‐7 (IA) Wind Erosion PM10 1.70E‐01 lbs/day/acre [14] 2.83E‐02 1.24E‐01FS 009‐7 (IA) PM2.5 2.55E‐02 lbs/day/acre [14] 4.25E‐03 1.86E‐02FS 010‐1 (IA) Wood Chip Loader 129,333 579 tons of green chips [06] PM 4.74E‐05 lbs/ton [13] 1.14E‐03 3.06E‐03FS 010‐1 (IA) Material Handling PM10 2.24E‐05 lbs/ton [13] 5.40E‐04 1.45E‐03FS 010‐1 (IA) PM2.5 3.39E‐06 lbs/ton [13] 8.18E‐05 2.19E‐04FS 010‐2 (IA) Wood Chip Loader 129,333 579 tons of green chips [06] PM 4.74E‐05 lbs/ton [13] 1.14E‐03 3.06E‐03FS 010‐2 (IA) Material Handling PM10 2.24E‐05 lbs/ton [13] 5.40E‐04 1.45E‐03FS 010‐2 (IA) PM2.5 3.39E‐06 lbs/ton [13] 8.18E‐05 2.19E‐04FS 010‐3 (IA) Wood Chip Loader 129,333 579 tons of green chips [06] PM 4.74E‐05 lbs/ton [13] 1.14E‐03 3.06E‐03FS 010‐3 (IA) Material Handling PM10 2.24E‐05 lbs/ton [13] 5.40E‐04 1.45E‐03FS 010‐3 (IA) PM2.5 3.39E‐06 lbs/ton [13] 8.18E‐05 2.19E‐04FS 010‐4 (IA) Wood Chip Loader 129,333 579 tons of green chips [06] PM 4.74E‐05 lbs/ton [13] 1.14E‐03 3.06E‐03FS 010‐4 (IA) Material Handling PM10 2.24E‐05 lbs/ton [13] 5.40E‐04 1.45E‐03FS 010‐4 (IA) PM2.5 3.39E‐06 lbs/ton [13] 8.18E‐05 2.19E‐04FS 010‐5 (IA) Wood Chip Loader 129,333 579 tons of green chips [06] PM 4.74E‐05 lbs/ton [13] 1.14E‐03 3.06E‐03FS 010‐5 (IA) Material Handling PM10 2.24E‐05 lbs/ton [13] 5.40E‐04 1.45E‐03FS 010‐5 (IA) PM2.5 3.39E‐06 lbs/ton [13] 8.18E‐05 2.19E‐04

Emission Factor Emission RateThroughput


FS 010‐6 (IA) Wood Chip Loader 554,286 2,480 tons of green chips [06] PM 4.74E‐05 lbs/ton [13] 4.90E‐03 1.31E‐02FS 010‐6 (IA) Material Handling PM10 2.24E‐05 lbs/ton [13] 2.32E‐03 6.21E‐03FS 010‐6 (IA) PM2.5 3.39E‐06 lbs/ton [13] 3.51E‐04 9.40E‐04FS 010‐7 (IA) Wood Chip Loader 739,048 3,307 tons of green chips [06] PM 4.74E‐05 lbs/ton [13] 6.53E‐03 1.75E‐02FS 010‐7 (IA) Material Handling PM10 2.24E‐05 lbs/ton [13] 3.09E‐03 8.28E‐03FS 010‐7 (IA) PM2.5 3.39E‐06 lbs/ton [13] 4.67E‐04 1.25E‐03FS 011 (IA) Purchased Chip Truck Dump 300,000 1,680 tons of green chips [08] PM 4.74E‐05 lbs/ton [13] 3.32E‐03 7.11E‐03FS 011 (IA) Purchased Chip Truck Dump PM10 2.24E‐05 lbs/ton [13] 1.57E‐03 3.36E‐03FS 011 (IA) Purchased Chip Truck Dump PM2.5 3.39E‐06 lbs/ton [13] 2.37E‐04 5.09E‐04FS 012 (IA) Purchased Chip Conveying 300,000 1,680 tons of green chips [08] PM 4.74E‐05 lbs/ton [13] 3.32E‐03 7.11E‐03FS 012 (IA) Purchased Chip Conveying PM10 2.24E‐05 lbs/ton [13] 1.57E‐03 3.36E‐03FS 012 (IA) Purchased Chip Conveying PM2.5 3.39E‐06 lbs/ton [13] 2.37E‐04 5.09E‐04FS 401 (IA) Hog Fuel Boiler Truck Dump 324,120 41 tons hog fuel [22] PM 5.67E‐05 lbs/ton [13] 9.61E‐05 9.18E‐03FS 401 (IA) Hog Fuel Boiler Truck Dump PM10 2.68E‐05 lbs/ton [13] 4.54E‐05 4.34E‐03FS 401 (IA) Hog Fuel Boiler Truck Dump PM2.5 4.06E‐06 lbs/ton [13] 6.88E‐06 6.58E‐04FS 402 (IA) Bark & Sludge Conveying 324,120 41 tons hog fuel [22] PM 5.67E‐05 lbs/ton [13] 3.97E‐03 8.50E‐03FS 402 (IA) Bark & Sludge Conveying PM10 2.68E‐05 lbs/ton [13] 1.88E‐03 4.02E‐03FS 402 (IA) Bark & Sludge Conveying PM2.5 4.06E‐06 lbs/ton [13] 2.84E‐04 6.09E‐04FUGI 3 Wastewater Treatment Plant Primary Clarifier 547,500 1500 ADTUBP [23] Acetone 4.70E‐03 lbs/VMT [26] 2.94E‐01 1.29E+00FUGI 3 Wastewater Treatment Plant Primary Clarifier Chloroform 8.20E‐04 lbs/VMT 5.13E‐02 2.24E‐01FUGI 3 Wastewater Treatment Plant Primary Clarifier Methanol 5.18E‐02 lbs/VMT [28] 3.24E+00 1.42E+01

#REF! #REF! Sulfur ‐ Total Reduced 3.06E‐07 lbs/VMT [27] 1.91E‐05 8.38E‐05#REF! #REF! Volatile Organic Compounds 5.18E‐02 lbs/VMT [28] 3.24E+00 1.42E+01

FS 603 (IA) Wastewater Treatment Plant Secondary Clarifier #1 547,500 1500 ADTUBP [23] Chloroform 2.12E‐04 lbs/VMT [29] 1.33E‐02 5.81E‐02FS 603 (IA) Wastewater Treatment Plant Secondary Clarifier #1 Hydrogen Sulfide 6.30E‐07 lbs/VMT [27] 3.94E‐05 1.72E‐04FS 603 (IA) Wastewater Treatment Plant Secondary Clarifier #1 Sulfur ‐ Total Reduced 9.00E‐07 lbs/VMT [27] 5.63E‐05 2.46E‐04FS 603 (IA) Wastewater Treatment Plant Secondary Clarifier #1 Volatile Organic Compounds 6.75E‐04 lbs/VMT [30] 4.22E‐02 1.85E‐01FS 604 (IA) Wastewater Treatment Plant Secondary Clarifier #2 547,500 1500 ADTUBP [23] Chloroform 2.12E‐04 lbs/VMT [29] 1.33E‐02 5.81E‐02FS 604 (IA) Wastewater Treatment Plant Secondary Clarifier #2 Hydrogen Sulfide 6.30E‐07 lbs/VMT [27] 3.94E‐05 1.72E‐04FS 604 (IA) Wastewater Treatment Plant Secondary Clarifier #2 Sulfur ‐ Total Reduced 9.00E‐07 lbs/VMT [27] 5.63E‐05 2.46E‐04FS 604 (IA) Wastewater Treatment Plant Secondary Clarifier #2 Volatile Organic Compounds 6.75E‐04 lbs/VMT [30] 4.22E‐02 1.85E‐01FS 701 (IA) Paved Roads at Mill 29,900 miles traveled/year [25] PM 2.12E‐01 lbs/VMT [24] 3.17E+00FS 701 (IA) Annual Emissions PM10 4.24E‐02 lbs/VMT [24] 6.34E‐01FS 701 (IA) PM2.5 1.04E‐02 lbs/VMT [24] 1.56E‐01FS 701 (IA) Paved Roads at Mill 5.85 miles traveled/hour [25] PM 2.34E‐01 lbs/VMT [24] 1.37E+00FS 701 (IA) Hourly Emissions PM10 4.67E‐02 lbs/VMT [24] 2.73E‐01FS 701 (IA) PM2.5 1.15E‐02 lbs/VMT [24] 6.70E‐02FUGI 5 Unpaved Roads 27,900 miles traveled/year [25] PM 1.38E+00 lbs/VMT [24] 1.93E+01FUGI 5 Annual Emissions PM10 3.94E‐01 lbs/VMT [24] 5.50E+00FUGI 5 PM2.5 3.94E‐02 lbs/VMT [24] 5.50E‐01FUGI 5 Unpaved Roads 7.40 miles traveled/hour [25] PM 2.18E+00 lbs/VMT [24] 1.62E+01FUGI 5 Hourly Emissions PM10 6.22E‐01 lbs/VMT [24] 4.61E+00FUGI 5 PM2.5 6.22E‐02 lbs/VMT [24] 4.61E‐01FUGI 4 Paved Roads at Process Center 32,200 miles traveled/year [25] PM 3.32E‐01 lbs/VMT [24] 5.34E+00FUGI 4 Annual Emissions PM10 6.63E‐02 lbs/VMT [24] 1.07E+00FUGI 4 PM2.5 1.63E‐02 lbs/VMT [24] 2.62E‐01FUGI 4 Paved Roads at Process Center 10.80 miles traveled/hour [25] PM 3.65E‐01 lbs/VMT [24] 3.94E+00FUGI 4 Hourly Emissions PM10 7.30E‐02 lbs/VMT [24] 7.89E‐01FUGI 4 PM2.5 1.79E‐02 lbs/VMT [24] 1.94E‐01


Notes[01]

[02][03]

[04]

[05]

[06][07]

[08]

[09]

[10]

[11]

[12][13]

[14]Bark Pilea Chip Piles

PM 2.98 0.34 lb/acre/day PM10*2PM10 1.49 0.17 lb/acre/dayPM2.5 0.2235 0.0255 lb/acre/day PM2.5:PM10 ratio = 0.075/0.5

[15][16][17][18]

[19][20][21][22]

Maximum hourly = 40.7 tons hog fuel/hourMaximum annual = 324120 tons hog fuel/year

[23] Pulp mill throughput[24] See "Fug Road Usage" for details[25][26] Water Sampling Data[27] Engineering Calculation (lb/adt)[28] Engineering Calculation and 30% increase in mill capture due to Cluster Rules[29] Analytical Data 4/94 (lb/adt) ‐ emission factor is an average of the calculated winter emission factor and the summer emission factor.[30] January 1999 Air Toxics Review or Efficiency Improvement and Boiler #2 Projects March 1999[31]

[32] Pile size estimated from aerial imagery

Daily throughput based on 7000 green tons chipped per day plus 1680 green tons purchased per day and apportioned to each pile based on area

Daily throughput based on 3500 BDT per day adjusted to an as‐received basis using 50% moisture in chips Annual throughput based on 820,000 BDT chips required to operate mill at current limits adjusted to an as‐received basis using 50% moisture in chips

Daily throughput based on approximate bark percentage of roundwood deliveriesAnnual throughput based on Boiler #2 12‐month rolling fuel usage limitPile size estimated from aerial imagery

Annual and daily throughputs assumes all bark conveyed is handled at the bark pile

Daily throughput based on 60% of 3500 BDT of debarked logs per day

Emission calculations were conducted to deteremine the maximum emissions from fugitive sources. However, the actual emissions will vary based on meterological conditions. Air dispersion modeling would be conducted using variations of these calculations. For example, the wind erosion calculations for the air dispersion modeling would vary with the wind speed from the meterologica data.

Daily VMT based on the estimated daily distance traveled by the Rejects truckAnnual VMT assumes the daily VMT for 15 daily events per yearFrom SCC for PM10 from log debarking from EPA 450/4‐90‐003, p. 143 and 80% control from the building. Assume PM2.5 = PM10

New Bark Hog installed in 2003 that is fully enclosed. Only emissions now are from drop to conveyor. Calculated using AP‐42 13.2.4‐4. See Material Handling tab for details

Daily VMT based on the estimated daily distance traveled by the Chip Loaders on the pilesAnnual VMT assumes the daily VMT at 365 days/yearSee Pile Traffic EF tab for details

Calculated using AP‐42 13.2.4 ‐ Equation 1. See Material Handling tab for details

Calculated using EPA 450/3‐88‐008 Equation 4‐9.

Calculated using AP‐42 13.2.2. See Pile Traffic tab for details

Assume emissions from overs and rejects chipping are similar to wood chippingAssume PM10 = PM2.5 because no additional information is available for this source type

Calculated using AP‐42 13.2.4 ‐ Equation 1. Assumes an average of 3.25 conveyor drops. See Chip Handling tab for detailsFrom chip cyclone TPM mean emission factor from NCASI Compilation of Criteria Air Pollutant Emissions Data for Sources at Pulp and Paper Mills Including Boilers, Technical Bulletin 884,

Assume emissions from chip blowers are similar to chip cyclones

Assume annual hog fuel handing is equivalent throughput to boiler hog fuel firing. Assume maximum hourly hog fuel firing is equivalent to boiler hog fuel firing + 10% for surge

Estimate based on maximum pulp production rates

Daily throughput based on 60 purchased chip trucks per day at 28 tons chips on an as‐received basisAnnual throughput based on 2002 modeling throughput of 150,000 BDT adjusted to an as‐received basis using 50% moisture in the chips

Daily throughput of 2700 BDT based on the throughput required to provide chips for the current maximum daily production rate of the pulp millAnnual throughput is 820,000 BDT based on the throughput required to provide chips for the current maximum annual production rate of the pulp mill. Assumes all chips routed through Annual and daily throughputs assumes all bark conveyed is routed through the bark hog


Boise White Paper, LLC ‐ International Falls, MNPTE Calculations ‐ GHGRevised 7/31/2015

Stack Emission Unit/ SI Throughput[02] Material Throughput MaterialID ID Description Pollutant Worst Case Fuel

(lb/Unit) Unit (lb/hr) (tons/yr) (lb/hr) (tons/yr)STRU 150 EQUI 9 Recovery Furnace (BLS) Biogenic CO2 1 BLS 770.9 MMBtu/hr 6,152,640 MMBtu/year 2.08E+02 lb/MMBtu 1.60E+05 6.40E+05 160439 640226STRU 150 EQUI 9 Recovery Furnace (BLS) Biogenic CH4 25 BLS 770.9 MMBtu/hr 6,152,640 MMBtu/year 4.19E‐03 lb/MMBtu 3.23E+00 1.29E+01 80.73 322.15STRU 150 EQUI 9 Recovery Furnace (BLS) Biogenic N2O 298 BLS 770.9 MMBtu/hr 6,152,640 MMBtu/year 9.26E‐04 lb/MMBtu 7.14E‐01 2.85E+00 212.72 848.84STRU 150 EQUI 9 Recovery Furnace (BLS) CO2e 160732 641397STRU 111 EQUI 13 Lime Kiln CO2 1 Natural Gas 70.0 MMBtu/hr 613,200 MMBtu/year 1.17E+02 lb/MMBtu 8.19E+03 3.59E+04 8188 35865STRU 111 EQUI 13 Lime Kiln CH4 25 Natural Gas 70.0 MMBtu/hr 613,200 MMBtu/year 5.95E‐03 lb/MMBtu 4.17E‐01 1.83E+00 10.42 45.63STRU 111 EQUI 13 Lime Kiln N2O 298 Natural Gas 70.0 MMBtu/hr 613,200 MMBtu/year 0.00E+00 lb/MMBtu 0.00E+00 0.00E+00 0.00 0.00STRU 111 EQUI 13 Lime Kiln CO2e 8199 35910STRU 18 EQUI 15 Boiler #1 CO2 1 Natural Gas 398.0 MMBtu/hr 3,486,480 MMBtu/year 1.17E+02 lb/MMBtu 4.66E+04 2.04E+05 46556 203917STRU 18 EQUI 15 Boiler #1 CH4 25 Natural Gas 398.0 MMBtu/hr 3,486,480 MMBtu/year 2.20E‐03 lb/MMBtu 8.77E‐01 3.84E+00 21.94 96.08STRU 18 EQUI 15 Boiler #1 N2O 298 Natural Gas 398.0 MMBtu/hr 3,486,480 MMBtu/year 2.20E‐04 lb/MMBtu 8.77E‐02 3.84E‐01 26.15 114.53STRU 18 EQUI 15 Boiler #1 CO2e 46605 204128STRU 146 EQUI 16 Boiler #2 Biogenic CO2 1 Bark 395.0 MMBtu/hr 3,460,200 MMBtu/year 2.07E+02 lb/MMBtu 8.17E+04 3.58E+05 81683 357770STRU 146 EQUI 16 Boiler #2 Biogenic CH4 25 Bark 395.0 MMBtu/hr 3,460,200 MMBtu/year 1.59E‐02 lb/MMBtu 6.27E+00 2.75E+01 156.75 686.55STRU 146 EQUI 16 Boiler #2 Biogenic N2O 298 Bark 395.0 MMBtu/hr 3,460,200 MMBtu/year 7.94E‐03 lb/MMBtu 3.13E+00 1.37E+01 934.21 4091.85STRU 146 EQUI 16 Boiler #2 CO2e 82774 362548STRU 146 EQUI 16 Boiler #2 Biogenic CO2 1 Sludge [04] 327.5 MMBtu/hr 514,107 MMBtu/year 2.61E+02 lb/MMBtu[03] 8.53E+04 6.70E+04 85326 66967STRU 146 EQUI 16 Boiler #2 Biogenic CH4 25 Sludge [04] 327.5 MMBtu/hr 514,107 MMBtu/year 7.05E‐02 lb/MMBtu 2.31E+01 1.81E+01 577.65 453.36STRU 146 EQUI 16 Boiler #2 Biogenic N2O 298 Sludge [04] 327.5 MMBtu/hr 514,107 MMBtu/year 9.26E‐03 lb/MMBtu 3.03E+00 2.38E+00 903.73 709.28STRU 146 EQUI 16 Boiler #2 CO2e 86807 68130STRU 147 EQUI 17 Boiler #3 CO2 1 Natural Gas 373.0 MMBtu/hr 3,267,480 MMBtu/year 1.17E+02 lb/MMBtu 4.36E+04 1.91E+05 43632 191108STRU 147 EQUI 17 Boiler #3 CH4 25 Natural Gas 373.0 MMBtu/hr 3,267,480 MMBtu/year 2.20E‐03 lb/MMBtu 8.22E‐01 3.60E+00 20.56 90.04STRU 147 EQUI 17 Boiler #3 N2O 298 Natural Gas 373.0 MMBtu/hr 3,267,480 MMBtu/year 2.20E‐04 lb/MMBtu 8.22E‐02 3.60E‐01 24.51 107.33STRU 147 EQUI 17 Boiler #3 CO2e 43677 191306STRU 30 EQUI 18 Boiler # 9 CO2 1 Natural Gas 205.0 MMBtu/hr 1,795,800 MMBtu/year 1.17E+02 lb/MMBtu 2.40E+04 1.05E+05 23980 105033STRU 30 EQUI 18 Boiler # 9 CH4 25 Natural Gas 205.0 MMBtu/hr 1,795,800 MMBtu/year 2.20E‐03 lb/MMBtu 4.52E‐01 1.98E+00 11.30 49.49STRU 30 EQUI 18 Boiler # 9 N2O 298 Natural Gas 205.0 MMBtu/hr 1,795,800 MMBtu/year 2.20E‐04 lb/MMBtu 4.52E‐02 1.98E‐01 13.47 58.99STRU 30 EQUI 18 Boiler # 9 CO2e 24005 105141GHG emissions for Emergency generators are listed on PTE page CO2e 370025 1540431

[01] Emission factors and calculations based on 40 CFR Part 98.(as of July 9, 2015)

[02] Maximum throughput:Recovery Furnace: max BLS per day and per 12‐month rolling average

11.6 MMBtu/ton BLSBoilers max MMBtu/hr design

8760 hours/yearLime Kiln Maximum natural gas

[03] Emission factor used is highest Biomass Solid emission factor (Agricultural Byproducts). Table C‐1 does not indicate if the Emission Factor is wet or dry, so no conversion was made. This is the most conservative approach.

[04] MMBtu/hr and MMBtu/year based on permit limit of 39.7 tons/hr and 5193 tons/month respectively, using HHV of 8.25 MMBtu/ton from Part 98 Table C‐1

Default CO2 Emission Factors and High Heat Values for Various Types of Fuel

Coal and coke mmBtu/short ton kg CO2/mmBtu lb CO2/mmBtuAnthracite 25.09 103.69 228.59 Bituminous 24.93 93.28 205.65 Subbituminous 17.25 97.17 214.22 Lignite 14.21 97.72 215.43 Coal Coke 24.8 113.67 250.60 Mixed (Commercial sector) 21.39 94.27 207.83 Mixed (Industrial coking) 26.28 93.90 207.01 Mixed (Industrial sector) 22.35 94.67 208.71 Mixed (Electric Power sector) 19.73 95.52 210.58 Natural gas mmBtu/scf kg CO2/mmBtu lb CO2/mmBtu(Weighted U.S. Average) 1.03E‐03 53.06 116.98

Global Warming Potential

Fuel Type Default high heat value

Table C‐1 to Subpart C of Part 98—Default CO 2 Emission Factors and High Heat Values for Various Types of Fuel

Hourly Throughput

Default CO2 Emissions Factor

Annual Throughput

Emissions EmissionsEmissionFactor[01]

Maximum CO2e


Petroleum products mmBtu/gallon kg CO2/mmBtu lb CO2/mmBtuDistillate Fuel Oil No. 1 0.139 73.25 161.49 Distillate Fuel Oil No. 2 0.138 73.96 163.05 Distillate Fuel Oil No. 4 0.146 75.04 165.43 Residual Fuel Oil No. 5 0.14 72.93 160.78 Residual Fuel Oil No. 6 0.15 75.10 165.57 Used Oil 0.138 74.00 163.14 Kerosene 0.135 75.20 165.79 Liquefied petroleum gases (LPG) 1 0.092 61.71 136.05 Propane1 0.091 62.87 138.60 Propylene2 0.091 67.77 149.41 Ethane1 0.068 59.60 131.39 Ethanol 0.084 68.44 150.88 Ethylene2 0.058 65.96 145.42 Isobutane1 0.099 64.94 143.17

Isobutylene1 0.103 68.86 151.81

Butane1 0.103 64.77 142.79

Butylene1 0.105 68.72 151.50 Naphtha (<401 deg F) 0.125 68.02 149.96 Natural Gasoline 0.11 66.88 147.44 Other Oil (>401 deg F) 0.139 76.22 168.03 Pentanes Plus 0.11 70.02 154.37 Petrochemical Feedstocks 0.125 71.02 156.57 Petroleum Coke 0.143 102.41 225.77 Special Naphtha 0.125 72.34 159.48 Unfinished Oils 0.139 74.54 164.33 Heavy Gas Oils 0.148 74.92 165.17 Lubricants 0.144 74.27 163.74 Motor Gasoline 0.125 70.22 154.81 Aviation Gasoline 0.12 69.25 152.67 Kerosene‐Type Jet Fuel 0.135 72.22 159.22 Asphalt and Road Oil 0.158 75.36 166.14 Crude Oil 0.138 74.54 164.33 Other fuels—solid mmBtu/short ton kg CO2/mmBtu lb CO2/mmBtuMunicipal Solid Waste 9.953 90.70 199.96 Tires 28 85.97 189.53 Plastics 38 75.00 165.35 Petroleum Coke 30 102.41 225.77 Other fuels—gaseous mmBtu/scf kg CO2/mmBtu lb CO2/mmBtuBlast Furnace Gas 9.20E‐05 274.32 604.77 Coke Oven Gas 5.99E‐04 46.85 103.29 Propane Gas 2.52E‐03 61.46 135.49 Fuel Gas4 1.39E‐03 59.00 130.07 Biomass fuels—solid mmBtu/short ton kg CO2/mmBtu lb CO2/mmBtu

Wood and Wood Residuals (dry basis)5 17.48 93.80 206.79 Agricultural Byproducts 8.25 118.17 260.52 Peat 8 111.84 246.56 Solid Byproducts 10.39 105.51 232.61 Biomass fuels—gaseous mmBtu/scf kg CO2/mmBtu lb CO2/mmBtuLandfill Gas 4.85E‐04 52.07 114.79 Other Biomass Gases 6.55E‐04 52.07 114.79 Biomass Fuels—Liquid mmBtu/gallon kg CO2/mmBtu lb CO2/mmBtuEthanol 0.084 68.44 150.88 Biodiesel (100%) 0.128 73.84 162.79 Rendered Animal Fat 0.125 71.06 156.66 Vegetable Oil 0.12 81.55 179.79

5Use the following formula to calculate a wet basis HHV for use in Equation C‐1: HHV w = ((100 − M)/100)*HHVdwhere HHVw = wet basis HHV, M = moisture content (percent) and HHVd = dry basis HHV from Table C‐1.

4Reporters subject to subpart X of this part that are complying with §98.243(d) or subpart Y of this part may only use the default HHV and the default CO2 emission factor for fuel gas combustion under the conditions prescribed in §98.243(d)(2)(i) and (d)(2)(ii) and §98.252(a)(1) and (a)(2), respectively. Otherwise, reporters subject to subpart X or subpart Y shall use either Tier 3 (Equation C‐5) or Tier 4.

3Use of this default HHV is allowed only for: (a) Units that combust MSW, do not generate steam, and are allowed to use Tier 1; (b) units that derive no more than 10 percent of their annual heat input from MSW and/or tires; and (c) small batch incinerators that combust no more than 1,000 tons of MSW per year.

2Ethylene HHV determined at 41 °F (5 °C) and saturation pressure.

1The HHV for components of LPG determined at 60 °F and saturation pressure with the exception of ethylene.

[78 FR 71950, Nov. 29, 2013]


Table C‐2 to Subpart C of Part 98—Default CH4 and N2O Emission Factors for Various Types of Fuel

Fuel Type

CH4 emission factor (kg

CH4/mmBtu)Default N2O emission factor (kg

N2O/mmBtu)Default CH4 emission factor (lb CH4/mmBtu)

Default N2O emission factor (lb

N2O/mmBtu)

Coal and Coke (All fuel types in Table C‐1)

1.10E‐02 1.60E‐03 2.43E‐02 3.53E‐03

Natural Gas 1.00E‐03 1.00E‐04 2.20E‐03 2.20E‐04Petroleum (All fuel types in Table C‐1)

3.00E‐03 6.00E‐04 6.61E‐03 1.32E‐03

Fuel Gas 3.00E‐03 6.00E‐04 6.61E‐03 1.32E‐03Municipal Solid Waste 3.20E‐02 4.20E‐03 7.05E‐02 9.26E‐03Tires 3.20E‐02 4.20E‐03 7.05E‐02 9.26E‐03Blast Furnace Gas 2.20E‐05 1.00E‐04 4.85E‐05 2.20E‐04Coke Oven Gas 4.80E‐04 1.00E‐04 1.06E‐03 2.20E‐04Biomass Fuels—Solid (All fuel types in Table C‐1, except wood and wood residuals)

3.20E‐02 4.20E‐03 7.05E‐02 9.26E‐03

Wood and wood residuals 7.20E‐03 3.60E‐03 1.59E‐02 7.94E‐03Biomass Fuels—Gaseous (All fuel types in Table C‐1)

3.20E‐03 6.30E‐04 7.05E‐03 1.39E‐03

Biomass Fuels—Liquid (All fuel types in Table C‐1)

1.10E‐03 1.10E‐04 2.43E‐03 2.43E‐04

[78 FR 71952, Nov. 29, 2013]

Global Warming Potentials

Name CAS No. Chemical formulaGlobal warming potential (100 yr.)

Carbon dioxide 124‐38‐9 CO2 1Methane 74‐82‐8 CH4 25 See Note ANitrous oxide 10024‐97‐2 N2O 298 See Note A

Table AA‐1 to Subpart AA of Part 98—Kraft Pulping Liquor Emissions Factors for Biomass‐Based CO 2, CH4, and N2O

aCO2 CH4 N2OaCO2 CH4 N2O

North American Softwood 94.4 0.0019 0.00042 208.11 0.0042 0.00093 North American Hardwood 93.7 0.0019 0.00042 206.57 0.0042 0.00093 Bagasse 95.5 0.0019 0.00042 210.54 0.0042 0.00093 Bamboo 93.7 0.0019 0.00042 206.57 0.0042 0.00093 Straw 95.1 0.0019 0.00042 209.66 0.0042 0.00093 a Includes emissions from both the recovery furnace and pulp mill lime kiln.[78 FR 71965, Nov. 29, 2013]

Table AA‐2 to Subpart AA of Part 98—Kraft Lime Kiln and Calciner Emissions Factors for CH 4 and N2O

CH4 N2O CH4 N2O CH4 N2O CH4 N2O

Residual Oil (any type) 0.0027 0 0.0027 0.0003 0.0060 0 0.0060 0.00066 Distillate Oil (any type) 0.0027 0 0.0027 0.0004 0.0060 0 0.0060 0.00088 Natural Gas 0.0027 0 0.0027 0.0001 0.0060 0 0.0060 0.00022 Biogas 0.0027 0 0.0027 0.0001 0.0060 0 0.0060 0.00022 Petroleum coke 0.0027 0 aNA aNA 0.0060 0 aNA aNAOther Fuels See Table C‐2 0 See Table C‐2 See Table C‐2 See Table C‐2 0 See Table C‐2 See Table C‐2

a Emission factors for kraft calciners are not available.[78 FR 71965, Nov. 29, 2013]

(lb/mmBtu HHV)Biomass‐based emissions factors

Kraft lime kilns

Note: Those employing this table are assumed to fall under the IPCC definitions of the “Energy Industry” or “Manufacturing Industries and Construction”. In all fuels except for coal the values for these two categories are identical. For coal combustion, those who fall within the IPCC “Energy Industry” category may employ a value of 1g of CH 4/mmBtu.

Kraft calcinersFossil fuel‐based emissions factors (lb/mmBtu HHV)Fossil fuel‐based emissions factors (kg/mmBtu HHV)

Kraft lime kilns Kraft calciners

Fuel

aThe GWP for this compound was updated in the final rule published on November 29, 2013 [78 FR 71904] and effective on January 1, 2014.

Wood furnish

(kg/mmBtu HHV)


Boise White Paper, LLC ‐ International Falls, MNPermit No. 07100002‐012 Permit Limits12/16/2013

Emission Unit APCDID Description ID Notes Parameter Permit Limit Unit/time

Facility Wide Black Liquor Solids Production 44,200 tons/month using 12‐month rolling averageEQUI 44 Brown Stock Decker HAPs ‐ Total 400 ppm by weight (process water)EQUI 9 Recovery Furnace Fuel Burned Natural Gas ‐

Fuel Burned 30 gallons/hour of distillate oil (#1 or #2)Process Throughput 1595 tons/day BLSProcess Throughput 44200 tons/mo 12‐month rolling averageCarbon Monoxide 538 lbs/hr using 24‐hour rolling averageCarbon Monoxide 2289 tons/yearNitrogen Oxides 110 lbs/hr using a 30‐day rolling averagePM < 10 micron 19.2 lbs/hrTotal Particulate Matter 27 lbs/hrSulfur Dioxide 106.2 lbs/hrSulfur Dioxide 200 tons/year using 12‐month rolling sumVolatile Organic Compounds 31.3 lbs/hrSulfur ‐ Total Reduced 5 ppm on a dry basis, corrected to 8% oxygen, using a 12‐hour

averageSulfur content of fuel 0.05 % by weight distillate oil sulfur contentOpacity 20 % opacity using a 6‐minute average, except for one 6‐minute

period per hour of not more than 27% opacityEQUI 13 Lime Kiln Fuel Burned Natural Gas ‐

Production 198 tons/day lime, calculated on a 12‐hour block averageCarbon Monoxide 23.7 lbs/hrNitrogen Oxides 34.9 lbs/hr, using a 3‐hour averagePM < 10 micron 12.7 lbs/hrTotal Particulate Matter 12.7 lbs/hrSulfur Dioxide 13.5 lbs/hrSulfur ‐ Total Reduced 8 ppm on a dry basis, corrected to 10% oxygen, using a 12‐hour

average

Volatile Organic Compounds 11.4 lbs/hr, measured as C excluding methaneOpacity 20 percent using a 6‐minute average

EQUI 15 Boiler #1 Fuel Burned Natural Gas ‐44.0628 Nitrogen Oxides 0.2 lbs/million Btu heat input using 30‐day rolling average

PM < 10 micron 0.008 lb/MMBtu (PTE as stated in permit)PM < 10 micron 0.60 lb/MMBtu (limit as stated in permit)Total Particulate Matter 0.008 lb/MMBtu (PTE as stated in permit)Total Particulate Matter 0.60 lb/MMBtu (limit as stated in permit)Opacity 20 % opacity using a 6‐minute average, except for one 6‐minute

period per hour of not more than 60% opacityEQUI 16 Boiler #2 Fuel Burned Bark, Wood Refuse,

Wastewater Treatment Sludge, Paper, and Natural

Gas

‐

Fuel Usage 27010 tons/month using 12‐month rolling average. The fuel usage limit is for combined total of bark, wood refuse, paper, and sludge and shall be expressed in units of green tons/month.

Fuel Usage 39.7 tons/hour bark/wood refuse/sludge calculated on a six‐hour block average

Fuel Usage 5193 tons/month sludge using a 12‐month rolling averageCarbon Monoxide 800 lbs/hr using a 1‐hr average, 200 lbs/hr using a 12‐month rolling

averageCarbon Monoxide 200 lbs/hr using 12‐month rolling averageNitrogen Oxides 100.2 lbs/hr using 30‐day rolling averagePM < 10 micron 11.7 lbs/hrTotal Particulate Matter 13 lbs/hrSulfur Dioxide 39.5 lbs/hr 6‐hr rolling average. The limit does not apply when NCG

is being oxidized in the #2 Boiler.Sulfur Dioxide 9.4 lb/hr 12‐month rolling average limitVolatile Organic Compounds 40.2 lbs/hr measured as C excluding methaneOpacity 20 % opacity using 6‐minute average except for one six‐minute

period per hour of not more than 27% opacityEQUI 17 Boiler #3 Fuel Burned Natural Gas ‐

Carbon Monoxide 0.09 lbs/million Btu heat input Nitrogen Oxides 0.05 lbs/million Btu heat input using 30‐day Rolling AverageVolatile Organic Compounds 0.009 lbs/million Btu heat input, measured as C excluding methane

(3.4 lb/hr)Opacity 20 % Opacity using 6‐minute period per hour of not more than 27%

opacity

C:\Users\bkruege\Desktop\Boise calcs.xlsxPermit Limits for Emissions


Boiler #8 Fuel Burned Natural Gas(removed from permit) Fuel Usage 192 million Btu's/hour of natural gas heat input, calculated on a

twelve‐hour block averageCarbon Monoxide 0.09 lbs/million Btu heat input using 3‐hr averageNitrogen Oxides 0.05 lbs/million Btu heat input using 30 day rolling averageVolatile Organic Compounds 0.009 lbs/million Btu heat input measured as C excluding methane

(this is equivalent to 3.4 lb/hr)Opacity 20 % opacity using 6‐minute average, except for one six‐minute

period per hour of not more than 27%EQUI 18 Boiler # 9 Fuel Burned Natural Gas ‐

Carbon Monoxide 0.09 lbs/million Btu heat input using 3‐hr averageNitrogen Oxides 0.05 lbs/million Btu heat input using 30 day rolling averageVolatile Organic Compounds 0.009 lbs/million Btu heat input measured as C excluding methane

(this is equivalent to 3.4 lb/hr)Opacity 20 % opacity using 6‐minute average, except for one six‐minute

period per hour of not more than 27%EQUI 944 Wastewater Treatment

Plant Cooling TowerWastewater Process Throughput 1.70E+09 gallons/year using 12‐month rolling sum

EQUI 12 Paint Spray Booth Operating Hours 1044 hours/year using a 12‐month rolling sumOpacity 20 % opacity using 6‐minute averageTotal Particulate Matter 0.3 grains/dry standard cubic foot of exhaust gas

EQUI 24 Sludge Dryer Total Particulate Matter 0.3 grains/dry standard cubic foot of exhaust gasOpacity 20 % opacity using 6‐minute average

EQUI 25 Off‐Machine Coater HAPs ‐ Total 20 % of the mass of coating solids applied for each calander month for the web coating line

EQUI 940 Intermediate Chip Booster Station (Blower with Cyclone)

PM < 10 micron 2.9 lbs/hr

Total Particulate Matter 3 lbs/hrSTRU 20 Brown Stock Decker Sulfur Dioxide 0.02 lb/ADTUP

Sulfur ‐ Total Reduced 0.12 lb/ADTUPVolatile Organic Compounds 0.2 lb/ADTUP

COMG 11 ClO2 Generator Chlorine 0.17 lbs/hourChlorine Dioxide 2.2 lbs/hour

COMG 12 Bleach Plant Chlorine 0.41 lbs/hourChlorine Dioxide 1.2 lbs/hourHAPs ‐ Total 0.02 lbs/ ton of oven‐dried pulp

STRU 945 Smelt Dissolving Tank Process Throughput 1595 tons/day BLS measured as H2SNitrogen Oxides 0.033 lbs/ton BLS producedPM < 10 micron 7.3 lbs/hourTotal Particulate Matter 7.3 lbs/hourSulfur Dioxide 4.3 lbs/hrSulfur ‐ Total Reduced 0.033 lbs/ton BLS, measured as H2SVolatile Organic Compounds 0.09 lbs/ton BLS, measured as C excluding methane. (4.3 lb/hr)Opacity 20 percent using a 6‐minute average

COMG 6 LVHC NCG Incineration and Venting

Boilers 1 and 2 SO2 115 tons/year

TRS 8 ppmvd corrected to 10% O2Venting to Atmosphere 1 percent of total operating time

COMG 5 Boilers and Recovery Furnace

Combustion Sources (EU320, 420, 430, 440, 460)

NOx 3.67 tons/day

Facility Cap (Combustion Sources plus Lime Kiln and Smelt Dissolving Tank)

NOx 4.18 tons/day

COMG 423 HVLC NCG Incineration and Venting

Venting Venting to Atmosphere 4 percent of total operating time

C:\Users\bkruege\Desktop\Boise calcs.xlsxPermit Limits for Emissions


Boise White Paper, LLC ‐ International Falls, MNPaper Machine PM Calculation Table ‐ from 'Future Boise Process Center Emissions Calculations Spreadsheet'Compiled by Kirby Dahlquist as a part of the Woodyard PM Modeling ProjectTable last updated: July 2013Source B Emissions (EPA Protocol) Paper Machine #1

Stack Description Stack ID Stack Flow Stack Temp.Stack

Moisture(See Note 6) Stack Flow PM PM10 PM10 PM2.5 PM2.5 CPM PM PM10 PM2.5 CPM Total PM10 Total PM2.5

ACFM Deg. F % dscfm (gr/dscf) (gr/dscf) % of PM (gr/dscf) % of PM (gr/dscf) (lb/hr) (lb/hr) (lb/hr) (lb/hr) (lb/hr) (lb/hr)

Former and Press Section

Wet End Area Ventilation (See Note 1) 232 61,990.00 105 7.51% 53,582.03 0.00026 0.00019 0.00007 0.00023

RE 1 STRU 45 50,000.00 80 7.51% 45,219.13 0.00026 0.00019 0.00007 0.00023 0.100 0.072 0.027 0.089 0.161 0.116

FC1 STRU 40 50,000.00 110 8.70% 42,286.32 0.00026 0.00019 0.00007 0.00023 0.093 0.067 0.026 0.083 0.151 0.109

FC2 STRU 41 50,000.00 110 8.70% 42,286.32 0.00026 0.00019 0.00007 0.00023 0.093 0.067 0.026 0.083 0.151 0.109

FC3 STRU 99 50,000.00 110 8.70% 42,286.32 0.00026 0.00019 0.00007 0.00023 0.093 0.067 0.026 0.083 0.151 0.109

FC4 STRU 101 50,000.00 110 8.70% 42,286.32 0.00026 0.00019 0.00007 0.00023 0.093 0.067 0.026 0.083 0.151 0.109

RE 2 STRU 46 50,000.00 80 8.70% 44,635.56 0.00026 0.00019 0.00007 0.00023 0.098 0.071 0.027 0.088 0.159 0.115

Vacuum pump exhaust (See Note 2) 239 37,185.00 92 5.06% 33,766.84 0.00035 0.00021 0 0.00007 20 0.00016

Vacuum Pump Train Vent STRU 96 70,900.00 110 8.70% 59,962.00 0.00035 0.00021 0 0.00007 20 0.00016 0.182 0.108 0.036 0.082 0.190 0.118

Saveall STRU 41 3,400.00 92 5.06% 3,087.46 0.00035 0.00021 0 0.00007 20 0.00016 0.009 0.006 0.002 0.004 0.010 0.006

Vacuum Dearator STRU 103 7,000.00 92 5.06% 6,356.54 0.00035 0.00021 0 0.00007 20 0.00016 0.019 0.011 0.004 0.009 0.020 0.013

Vacuum foil Exhaust removed 1,300.00 92 5.06% 1,180.50 0.00035 0.00021 0 0.00007 20 0.00016 0.004 0.002 0.001 0.002 0.004 0.002

Forming Section Bottom STRU 98 68,000.00 110 8.70% 57,509.39 0.00035 0.00021 0 0.00007 20 0.00016 0.175 0.104 0.035 0.079 0.182 0.113

Forming Section Top STRU 100 68,000.00 110 8.70% 57,509.39 0.00035 0.00021 0 0.00007 20 0.00016 0.175 0.104 0.035 0.079 0.182 0.113

Dryer Section

Main dryer hood exhaust #1 (See Note 3) B1MND (237) 40,625.00 120 11.53% 32,719.20 <0.00007 0.00004 0 0.00001 20 0.00022

#1 Main Hood exhaust STRU 47 79,475.00 120 11.53% 64,008.82 <0.00007 0.00004 0 0.00001 20 0.00022 <0.036 0.022 0.005 0.122 0.144 0.127




After Hood Exhaust #5 STRU 52 79,475.00 120 11.53% 64,008.82 <0.00007 0.00004 0 0.00001 20 0.00022 <0.036 0.022 0.005 0.122 0.144 0.127

After Hood Exhaust #6 STRU 53 51,500.00 120 11.53% 41,477.88 <0.00007 0.00004 0 0.00001 20 0.00022 <0.023 0.014 0.004 0.079 0.093 0.082

Dry End Area Ventilation (See Note 4) 242 28,790.00 120 11.53% 23,187.34 0.00016 0.00010 0.00008 16 0.00033

SP-FC STRU 51 50,000.00 120 11.53% 40,269.79 0.00016 0.00010 55 0.00008 16 0.00033 0.056 0.035 0.028 0.113 0.148 0.141

RE#3 STRU 54 50,000.00 80 11.53% 43,252.73 0.00016 0.00010 55 0.00008 16 0.00033 0.060 0.038 0.030 0.121 0.159 0.151

Winder (Reel) Section

Size Press Pulper Exh. Fan STRU 97 15,000.00 85 5.06% 13,796.10 0.00035 0.00021 0 0.00007 20 0.00016 0.042 0.025 0.008 0.019 0.044 0.027

Winder Pulper Exh. Fan STRU 55 15,000.00 92 5.06% 13,621.15 0.00035 0.00021 0 0.00007 20 0.00016 0.041 0.025 0.008 0.019 0.043 0.027

55 16

1,266,065.00 Total lb/hr= 1.54 0.99 0.37 1.72 2.71 2.10

Average Production (tons/hr) [See Note 5] 55.0 Rated Capacity

Total lb/ton= 2.80E-02 1.81E-02 6.81E-03 3.13E-02 4.93E-02 3.81E-02 PM10 PM2.5

% of PM % of PM

65 24

C:\Users\bkruege\Desktop\Boise calcs.xlsxPoint Source ‐ Paper Mach (PM)


Paper Machine #2




Dryer Section






Dryer Vent off #2 PM STRU 34 43,000.00 120 11.53% 34,632.02 <0.00016 0.00010 0 0.00008 0.00074 <0.047 0.030 0.024 0.220 0.249 0.243

Vacuum Vent off #2 PM STRU 33 4,200.00 110 8.70% 3,552.05 0.00035 0.00021 0 0.00007 20 0.00016 0.011 0.006 0.002 0.005 0.011 0.007

Total lb/hr= 0.14 0.09 0.04 0.50 0.59 0.54



% of PM % of PM

61 27

Paper Machine #3




Dryer Section






North Exhaust Vent Between #3 and #4 PM STRU 89 43,000.00 120 11.53% 34,632.02 0.00026 0.00019 72 0.00007 0.00023 0.076 0.055 0.021 0.068 0.123 0.089

Vacuum Pumps ( #3 and #4 PM) (BM) STRU 88 8,400.00 90 5.00% 7,660.80 0.00035 0.00021 0 0.00007 20 0.00016 0.023 0.014 0.005 0.010 0.024 0.015

Total lb/hr= 0.17 0.11 0.04 0.31 0.43 0.35



% of PM % of PM

66 21



Paper Machine #4




Dryer Section






No. 4 PM Gas-fired Dryer (BM) STRU 90 43,000.00 120 11.53% 34,632.02 <0.00016 0.00010 0 0.00008 0.00033 <0.047 0.030 0.024 0.098 0.128 0.122

No. 4 PM Coater Dryer Exhaust STRU 95 40,000.00 120 11.53% 32,215.83 <0.00016 0.00010 0 0.00008 0.00033 <0.044 0.028 0.022 0.091 0.119 0.113

North Exhaust Vent Between #3 and #4 PM STRU 89 43,000.00 120 11.53% 34,632.02 0.00026 0.00019 72 0.00007 0.00023 0.076 0.055 0.021 0.068 0.123 0.089

Total lb/hr= 0.26 0.17 0.08 0.58 0.75 0.66



% of PM % of PM

65 31

Note 1: All wet end area ventilation PM concentrations assumed to be similar to vent E2FMR in table E5a, Appendix E, T.B. No. 942

Note 2: All vacuum pump exhausts are assumed to be similar in PM concentrations. Values are the average of all vacuum vents tested in T.B. No. 942

Note 3: Bleached free sheet dryer exhausts are expected to have similar PM concentrations to vent B1MND in table E2a, Appendix E, T.B. No. 942

Note 4: Dry end area ventilation PM concentrations are assumed to be similar to vent E2FMR as referenced in Note 1 above.

Note 5: Enter average production rate in tons per hour here.

Note 6: This calculation of dry standard flow rate ignores the pressure correction. The "Flow Calculations" worksheet can be used to determine moisture content from wet bulb/dry bulb, or relative humidity measurements

Note 7:Assume 5% moisture for 90 F vacuum pumps

Note 8: STRU 95 and STRU 34 are "IR exhaust" and assumed to be the same



Parameter Desc Subject Item ID Subject Item Designation Potential (lbs/hr) Unrestricted Pot (tpy) Limited (tpy)1,1,1‐Trichloroethane EQUI0000000241 532032004/EU326 0 0 0

EQUI0000000255 512032005/EU301 0 0 0EQUI0000000259 500032001/EU179 0 0 0EQUI0000000285 431032012/EU178 0 0 0EQUI0000000002 EU170 0 0 0EQUI0000000016 EU430 0.02 0.07 0.07EQUI0000000945 EU322 0 0 0EQUI0000000009 EU320 0 0 0EQUI0000000044 EU174 0 0 0EQUI0000000003 EU173 0 0 0EQUI0000000241 532032004/EU326 0 0 0EQUI0000000255 512032005/EU301 0 0 0EQUI0000000259 500032001/EU179 0 0 0EQUI0000000282 431032016/EU180 0 0 0EQUI0000000285 431032012/EU178 0 0 0EQUI0000000945 EU322 0 0 0EQUI0000000009 EU320 0 0 0EQUI0000000044 EU174 0.01 0.06 0.06

1,2‐Dichloroethane EQUI0000000241 532032004/EU326 0 0 0EQUI0000000255 512032005/EU301 0 0 0EQUI0000000259 500032001/EU179 0 0 0EQUI0000000285 431032012/EU178 0 0 0EQUI0000000002 EU170 0 0 0EQUI0000000016 EU430 0.01 0.05 0.05EQUI0000000945 EU322 0 0 0EQUI0000000009 EU320 0 0 0EQUI0000000044 EU174 0 0 0

1,2,4‐Trichlorobenzene EQUI0000000255 512032005/EU301 0 0 0EQUI0000000259 500032001/EU179 0 0 0EQUI0000000285 431032012/EU178 0 0 0EQUI0000000002 EU170 0 0 0EQUI0000000019 EU505 0.02 0.11 0.11EQUI0000000020 EU520 0.04 0.16 0.16EQUI0000000021 EU530 0.06 0.26 0.26

Parameter Desc Subject Item ID Subject Item Designation Potential (lbs/hr) Unrestricted Pot (tpy) Limited (tpy)EQUI0000000022 EU540 0.11 0.47 0.47EQUI0000000945 EU322 0 0.01 0.01EQUI0000000009 EU320 0.01 0.04 0.04EQUI0000000013 EU340 0 0.01 0.01EQUI0000000044 EU174 0.14 0.6 0.6EQUI0000000052 EU906 0 0 0EQUI0000000053 EU907 0 0 0EQUI0000000003 EU173 0 0 0

1,3‐Butadiene EQUI0000000255 512032005/EU301 0 0 0EQUI0000000259 500032001/EU179 0 0 0EQUI0000000285 431032012/EU178 0 0 0EQUI0000000009 EU320 0.01 0.04 0.04EQUI0000000013 EU340 0 0 0

1,4‐Dichlorobenzene (para‐) EQUI0000000016 EU430 0.11 0.5 0.52,4‐Dinitrophenol EQUI0000000016 EU430 0 0 0

EQUI0000000016 EU430 0 0 02,4,6‐Trichlorophenol EQUI0000000016 EU430 0 0 0Acetaldehyde EQUI0000000241 532032004/EU326 0 0 0

EQUI0000000242 532032002/EU325 0 0.01 0.01EQUI0000000255 512032005/EU301 0 0 0EQUI0000000259 500032001/EU179 0 0 0EQUI0000000282 431032016/EU180 0.01 0.05 0.05EQUI0000000285 431032012/EU178 0 0 0EQUI0000000002 EU170 0 0 0EQUI0000000016 EU430 0.06 0.28 0.28EQUI0000000019 EU505 0.06 0.25 0.25EQUI0000000020 EU520 0.08 0.36 0.36EQUI0000000021 EU530 1.16 5.06 5.06EQUI0000000022 EU540 1.56 6.83 6.83EQUI0000000945 EU322 0.07 0.29 0.29EQUI0000000009 EU320 0.25 0.98 0.98EQUI0000000013 EU340 0.07 0.33 0.33EQUI0000000044 EU174 0.07 0.3 0.3EQUI0000000003 EU173 0 0 0

Parameter Desc Subject Item ID Subject Item Designation Potential (lbs/hr) Unrestricted Pot (tpy) Limited (tpy)STRU0000000020 SV173 0 0 0

Acetophenone EQUI0000000016 EU430 0 0 0Acrolein EQUI0000000255 512032005/EU301 0 0 0

EQUI0000000259 500032001/EU179 0 0 0EQUI0000000285 431032012/EU178 0 0 0EQUI0000000002 EU170 0 0 0EQUI0000000016 EU430 0.05 0.23 0.23EQUI0000000019 EU505 0.03 0.11 0.11EQUI0000000020 EU520 0.04 0.16 0.16EQUI0000000021 EU530 0.05 0.24 0.24EQUI0000000022 EU540 0.01 0.41 0.41EQUI0000000945 EU322 0.02 0.06 0.06EQUI0000000013 EU340 0.01 0.03 0.03EQUI0000000044 EU174 0.01 0.06 0.06EQUI0000000052 EU906 0 0 0EQUI0000000053 EU907 0 0 0EQUI0000000003 EU173 0 0 0STRU0000000020 SV173 0 0 0

Antimony compounds EQUI0000000016 EU430 0 0 0EQUI0000000945 EU322 0 0 0EQUI0000000009 EU320 0 0 0EQUI0000000013 EU340 0 0 0

Arsenic compounds EQUI0000000015 EU420 0 0 0EQUI0000000016 EU430 0 0 0EQUI0000000017 EU440 0 0 0EQUI0000000018 EU460 0 0 0EQUI0000000945 EU322 0 0 0EQUI0000000009 EU320 0 0 0EQUI0000000013 EU340 0 0 0

Benzene EQUI0000000241 532032004/EU326 0 0 0EQUI0000000242 532032002/EU325 0 0 0EQUI0000000255 512032005/EU301 0 0 0EQUI0000000259 500032001/EU179 0 0 0EQUI0000000282 431032016/EU180 0 0 0

Parameter Desc Subject Item ID Subject Item Designation Potential (lbs/hr) Unrestricted Pot (tpy) Limited (tpy)EQUI0000000285 431032012/EU178 0 0 0EQUI0000000002 EU170 0 0 0EQUI0000000015 EU420 0 0 0EQUI0000000016 EU430 0.09 0.42 0.42EQUI0000000017 EU440 0 0 0EQUI0000000018 EU460 0 0 0EQUI0000000019 EU505 0 0.01 0.01EQUI0000000020 EU520 0 0.02 0.02EQUI0000000021 EU530 0.01 0.06 0.06EQUI0000000022 EU540 0.01 0.06 0.06EQUI0000000945 EU322 0 0 0EQUI0000000009 EU320 0.05 0.19 0.19EQUI0000000013 EU340 0.01 0.05 0.05EQUI0000000044 EU174 0 0.01 0.01EQUI0000000003 EU173 0 0 0STRU0000000020 SV173 0 0 0

Benzo(ghi)perylene EQUI0000000009 EU320 0 0 0Benzo[a]pyrene EQUI0000000016 EU430 0 0 0Beryllium Compounds EQUI0000000015 EU420 0 0 0

EQUI0000000016 EU430 0 0 0EQUI0000000017 EU440 0 0 0EQUI0000000018 EU460 0 0 0EQUI0000000945 EU322 0 0 0EQUI0000000009 EU320 0 0 0EQUI0000000013 EU340 0 0 0

Biphenyl EQUI0000000945 EU322 0 0.01 0.01EQUI0000000044 EU174 0 0 0

Bis(2‐ethylhexyl) phthalate EQUI0000000016 EU430 0 0 0EQUI0000000945 EU322 0 0 0EQUI0000000016 EU430 0 0.01 0.01EQUI0000000945 EU322 0 0 0

Cadmium compounds EQUI0000000015 EU420 0 0 0EQUI0000000016 EU430 0 0 0EQUI0000000017 EU440 0 0 0

Bromomethane (Methyl bromide)

Parameter Desc Subject Item ID Subject Item Designation Potential (lbs/hr) Unrestricted Pot (tpy) Limited (tpy)EQUI0000000018 EU460 0 0 0EQUI0000000945 EU322 0 0 0EQUI0000000009 EU320 0 0 0EQUI0000000013 EU340 0 0 0

Carbon Dioxide EQUI0000000015 EU420 46,556.00 203,917.00 203,917.00EQUI0000000016 EU430 85,326.00 357,770.00 357,770.00EQUI0000000017 EU440 43,632.00 191,108.00 119,108.00EQUI0000000018 EU460 23,980.00 105,033.00 105,033.00EQUI0000000009 EU320 160,439.00 640,226.00 640,226.00EQUI0000000013 EU340 8,188.00 35,865.00 35,865.00EQUI0000000941 EU918 34 8.49 8.49EQUI0000000942 EU919 248 62.1 62.1EQUI0000000943 EU920 209 52.2 52.2

Carbon Dioxide Equivalent EQUI0000000015 EU420 46,613.00 204,165.00 204,165.00EQUI0000000016 EU430 82,789.00 362,614.00 362,614.00EQUI0000000017 EU440 43,685.00 191,341.00 191,341.00EQUI0000000018 EU460 24,009.00 105,160.00 105,160.00EQUI0000000009 EU320 160,761.00 641,513.00 641,513.00EQUI0000000013 EU340 8,199.00 35,910.00 35,910.00EQUI0000000941 EU918 34.1 8.53 8.53EQUI0000000942 EU919 249 62.3 62.3EQUI0000000943 EU920 209 52.4 52.4

Carbon disulfide EQUI0000000255 512032005/EU301 0.01 0.04 0.04EQUI0000000259 500032001/EU179 0.01 0.04 0.04EQUI0000000285 431032012/EU178 0.01 0.04 0.04EQUI0000000016 EU430 0.05 0.22 0.22EQUI0000000019 EU505 0.01 0.05 0.05EQUI0000000020 EU520 0.16 0.68 0.68EQUI0000000021 EU530 0.01 0.05 0.05EQUI0000000022 EU540 0.04 0.19 0.19EQUI0000000945 EU322 0 0.01 0.01EQUI0000000009 EU320 0.04 0.18 0.18EQUI0000000013 EU340 0 0.02 0.02EQUI0000000044 EU174 0.01 0.02 0.02

Parameter Desc Subject Item ID Subject Item Designation Potential (lbs/hr) Unrestricted Pot (tpy) Limited (tpy)Carbon Monoxide EQUI0000000015 EU420 32.78 143.56 143.56

EQUI0000000016 EU430 800 876 876EQUI0000000017 EU440 33.57 147.04 147.04EQUI0000000018 EU460 33.6 147.17 147.17EQUI0000000945 EU322 0.55 2.18 2.18EQUI0000000024 EU903 0 0 0EQUI0000000009 EU320 538 2,289.00 2,289.00EQUI0000000013 EU340 23.7 104 104EQUI0000000941 EU918 2.18 0.55 0.55EQUI0000000942 EU919 1.44 0.36 0.36EQUI0000000943 EU920 13.4 3.35 3.35

Carbon tetrachloride EQUI0000000255 512032005/EU301 0 0 0EQUI0000000259 500032001/EU179 0 0 0EQUI0000000285 431032012/EU178 0 0 0EQUI0000000002 EU170 0 0 0EQUI0000000016 EU430 0 0.02 0.02EQUI0000000945 EU322 0 0 0EQUI0000000009 EU320 0 0 0EQUI0000000044 EU174 0.08 0.33 0.33STRU0000000020 SV173 0 0 0

Chlorine EQUI0000000016 EU430 0 0 0EQUI0000000241 532032004/EU326 0 0 0EQUI0000000255 512032005/EU301 0 0 0EQUI0000000259 500032001/EU179 0 0 0EQUI0000000282 431032016/EU180 0 0 0EQUI0000000285 431032012/EU178 0 0 0EQUI0000000016 EU430 0.01 0.03 0.03EQUI0000000019 EU505 0 0.01 0.01EQUI0000000020 EU520 0 0.01 0.01EQUI0000000021 EU530 0.01 0.05 0.05EQUI0000000022 EU540 0.01 0.03 0.03EQUI0000000945 EU322 0 0 0EQUI0000000009 EU320 0 0 0EQUI0000000013 EU340 0 0 0

Chlorobenzene (Monochlorobenzene)

Parameter Desc Subject Item ID Subject Item Designation Potential (lbs/hr) Unrestricted Pot (tpy) Limited (tpy)EQUI0000000044 EU174 0 0.01 0.01EQUI0000000052 EU906 0 0 0EQUI0000000053 EU907 0 0 0STRU0000000020 SV173 0 0 0

Chloroform EQUI0000000241 532032004/EU326 0 0 0EQUI0000000255 512032005/EU301 0 0 0EQUI0000000259 500032001/EU179 0 0 0EQUI0000000282 431032016/EU180 0.01 0.04 0.04EQUI0000000285 431032012/EU178 0 0 0EQUI0000000016 EU430 0 0 0EQUI0000000019 EU505 0 0.01 0.01EQUI0000000020 EU520 0.26 1.14 1.14EQUI0000000021 EU530 0.18 0.79 0.79EQUI0000000022 EU540 0.52 2.26 2.26EQUI0000000945 EU322 0 0 0EQUI0000000024 EU903 0 0 0EQUI0000000009 EU320 0 0 0EQUI0000000013 EU340 0 0.01 0.01EQUI0000000944 EU602 1.23 0.78 0.78EQUI0000000044 EU174 0 0.01 0.01EQUI0000000052 EU906 0.01 0.06 0.06EQUI0000000053 EU907 0.01 0.06 0.06FUGI0000000003 FS601 0.05 0.22 0.22STRU0000000020 SV173 0 0 0

Chloromethane EQUI0000000016 EU430 0.01 0.05 0.05EQUI0000000945 EU322 0.01 0.03 0.03EQUI0000000009 EU320 0 0.01 0.01EQUI0000000013 EU340 0.02 0.09 0.09EQUI0000000044 EU174 0 0 0EQUI0000000003 EU173 0 0 0

Chromium compounds EQUI0000000015 EU420 0 0 0EQUI0000000016 EU430 0 0 0EQUI0000000017 EU440 0 0 0EQUI0000000018 EU460 0 0 0

Parameter Desc Subject Item ID Subject Item Designation Potential (lbs/hr) Unrestricted Pot (tpy) Limited (tpy)EQUI0000000945 EU322 0 0 0EQUI0000000009 EU320 0 0 0EQUI0000000013 EU340 0 0 0

Cobalt compounds EQUI0000000015 EU420 0 0 0EQUI0000000016 EU430 0 0 0EQUI0000000017 EU440 0 0 0EQUI0000000018 EU460 0 0 0EQUI0000000945 EU322 0 0 0EQUI0000000009 EU320 0 0 0EQUI0000000013 EU340 0 0 0EQUI0000000044 EU174 1.12 4.89 4.89EQUI0000000003 EU173 0 0 0

Cumene (Isopropylbenzene) EQUI0000000255 512032005/EU301 0 0 0EQUI0000000259 500032001/EU179 0 0 0EQUI0000000285 431032012/EU178 0 0 0EQUI0000000016 EU430 0.01 0.03 0.03EQUI0000000019 EU505 0 0 0EQUI0000000020 EU520 0 0 0EQUI0000000021 EU530 0 0 0EQUI0000000022 EU540 0 0 0EQUI0000000945 EU322 0.01 0.04 0.04EQUI0000000009 EU320 0.11 0.43 0.43EQUI0000000013 EU340 0.02 0.08 0.08EQUI0000000255 512032005/EU301 0 0 0EQUI0000000259 500032001/EU179 0 0 0EQUI0000000285 431032012/EU178 0 0 0EQUI0000000002 EU170 0 0 0EQUI0000000016 EU430 0.01 0.05 0.05EQUI0000000019 EU505 0.03 0.11 0.11EQUI0000000020 EU520 0 0.01 0.01EQUI0000000021 EU530 0.07 0.31 0.31EQUI0000000022 EU540 0.11 0.48 0.48EQUI0000000945 EU322 0 0.01 0.01EQUI0000000009 EU320 0.01 0.05 0.05

Dichloromethane (Methylene chloride)

Cresols/Cresylic acid (isomers and mixture)

Parameter Desc Subject Item ID Subject Item Designation Potential (lbs/hr) Unrestricted Pot (tpy) Limited (tpy)EQUI0000000013 EU340 0 0.01 0.01EQUI0000000044 EU174 0 0.02 0.02EQUI0000000003 EU173 0 0 0STRU0000000020 SV173 0 0 0

Dimethyl sulfate EQUI0000000241 532032004/EU326 0 0 0Ethylbenzene EQUI0000000255 512032005/EU301 0 0 0

EQUI0000000259 500032001/EU179 0 0 0EQUI0000000285 431032012/EU178 0 0 0EQUI0000000016 EU430 0.01 0.06 0.06EQUI0000000019 EU505 0 0 0EQUI0000000020 EU520 0 0 0EQUI0000000021 EU530 0 0 0EQUI0000000022 EU540 0.01 0.03 0.03EQUI0000000945 EU322 0 0 0EQUI0000000009 EU320 0 0.01 0.01EQUI0000000013 EU340 0 0 0EQUI0000000012 EU902 1.81 0.94 0.94

Ethylene glycol EQUI0000000012 EU902 0 0 0Ethylene glycol monomethyl ether acetate EQUI0000000012 EU902 0 0 0Formaldehyde EQUI0000000255 512032005/EU301 0 0 0

EQUI0000000259 500032001/EU179 0 0 0EQUI0000000285 431032012/EU178 0 0 0EQUI0000000015 EU420 0.03 0.13 0.13EQUI0000000016 EU430 0 0 0EQUI0000000017 EU440 0.03 0.12 0.12EQUI0000000018 EU460 0.02 0.07 0.07EQUI0000000019 EU505 0.03 0.14 0.14EQUI0000000020 EU520 0.05 0.2 0.2EQUI0000000021 EU530 0.33 1.45 1.45EQUI0000000022 EU540 0.25 1.11 1.11EQUI0000000945 EU322 0.02 0.08 0.08EQUI0000000009 EU320 0.52 2.07 2.07EQUI0000000013 EU340 0.06 0.26 0.26

Parameter Desc Subject Item ID Subject Item Designation Potential (lbs/hr) Unrestricted Pot (tpy) Limited (tpy)EQUI0000000044 EU174 0.01 0.04 0.04EQUI0000000003 EU173 0 0 0STRU0000000020 SV173 0 0 0

HAPs ‐ Total EQUI0000000241 532032004/EU326 0.06 0.06EQUI0000000242 532032002/EU325 6.67 6.67EQUI0000000255 512032005/EU301 0.63 0.63EQUI0000000259 500032001/EU179 0.63 0.63EQUI0000000282 431032016/EU180 2.79 2.79EQUI0000000285 431032012/EU178 0.63 0.63EQUI0000000002 EU170 0 0 0EQUI0000000015 EU420 0 3.22 3.22EQUI0000000016 EU430 0 89.6 89.6EQUI0000000017 EU440 0 3.02 3.02EQUI0000000018 EU460 0 1.66 1.66EQUI0000000019 EU505 0 4.37 4.37EQUI0000000020 EU520 0 7.88 7.88EQUI0000000021 EU530 0 89.6 89.6EQUI0000000022 EU540 0 30.7 30.7EQUI0000000945 EU322 0 20.5 20.5EQUI0000000009 EU320 0 30.8 30.8EQUI0000000013 EU340 0 2.02 2.02EQUI0000000944 EU602 0 5.18 5.18EQUI0000000044 EU174 0 22.8 22.8EQUI0000000052 EU906 0.23 0.23EQUI0000000053 EU907 0.23 0.23EQUI0000000012 EU902 0 6.59 6.59EQUI0000000003 EU173 0 0 0FUGI0000000003 FS601 0 14.4 14.4STRU0000000020 SV173 0 0 0

Hexachlorobenzene EQUI0000000016 EU430 0 0 0EQUI0000000009 EU320 0 0 0

Hexane EQUI0000000241 532032004/EU326 0 0 0EQUI0000000255 512032005/EU301 0 0 0EQUI0000000259 500032001/EU179 0 0 0

Parameter Desc Subject Item ID Subject Item Designation Potential (lbs/hr) Unrestricted Pot (tpy) Limited (tpy)EQUI0000000282 431032016/EU180 0 0 0EQUI0000000285 431032012/EU178 0 0 0EQUI0000000002 EU170 0 0 0EQUI0000000015 EU420 0.7 3.08 3.08EQUI0000000016 EU430 0.12 0.51 0.51EQUI0000000017 EU440 0.66 2.88 2.88EQUI0000000018 EU460 0.36 1.58 1.58EQUI0000000019 EU505 0 0.01 0.01EQUI0000000020 EU520 0 0.02 0.02EQUI0000000021 EU530 0.01 0.03 0.03EQUI0000000022 EU540 0.08 0.37 0.37EQUI0000000945 EU322 0 0.01 0.01EQUI0000000009 EU320 0.01 0.04 0.04EQUI0000000013 EU340 0 0 0EQUI0000000044 EU174 0 0 0EQUI0000000003 EU173 0 0 0

Hydrochloric acid EQUI0000000016 EU430 0.14 0.62 0.62EQUI0000000009 EU320 3.99 15.9 15.9EQUI0000000013 EU340 0.02 0.1 0.1

Hydrofluoric acid EQUI0000000016 EU430 0.03 0.13 0.13Hydrogen Sulfide (H2S) EQUI0000000242 532032002/EU325 0 0 0

EQUI0000000002 EU170 0 0 0EQUI0000000009 EU320 1.33 5.3 5.3EQUI0000000013 EU340 0.32 1.4 1.4STRU0000000020 SV173 0 0 0

Lead Compounds EQUI0000000015 EU420 0 0 0EQUI0000000016 EU430 0 0.01 0.01EQUI0000000017 EU440 0 0 0EQUI0000000018 EU460 0 0 0EQUI0000000945 EU322 0 0 0EQUI0000000009 EU320 0 0 0EQUI0000000013 EU340 0 0 0

m‐Cresol EQUI0000000044 EU174 0.56 2.44 2.44Manganese compounds EQUI0000000015 EU420 0 0 0

Parameter Desc Subject Item ID Subject Item Designation Potential (lbs/hr) Unrestricted Pot (tpy) Limited (tpy)EQUI0000000016 EU430 0 0 0EQUI0000000017 EU440 0 0 0EQUI0000000018 EU460 0 0 0EQUI0000000009 EU320 0 0 0EQUI0000000013 EU340 0 0 0

Mercury Compounds EQUI0000000015 EU420 0 0 0EQUI0000000016 EU430 0 0 0EQUI0000000017 EU440 0 0 0EQUI0000000018 EU460 0 0 0EQUI0000000945 EU322 0 0 0EQUI0000000009 EU320 0 0 0EQUI0000000013 EU340 0 0 0

Methane EQUI0000000015 EU420 21.94 96.08 96.08EQUI0000000016 EU430 577.65 686.55 686.55EQUI0000000017 EU440 20.56 90.04 90.04EQUI0000000018 EU460 11.3 49.49 49.49EQUI0000000009 EU320 80.73 322,015.00 322.15EQUI0000000013 EU340 10.42 45.63 45.63EQUI0000000941 EU918 0 0 0EQUI0000000942 EU919 0.01 0 0EQUI0000000943 EU920 0.01 0 0

Methanol EQUI0000000241 532032004/EU326 0.01 0.06 0.06EQUI0000000242 532032002/EU325 1.52 6.64 6.64EQUI0000000255 512032005/EU301 0.13 0.57 0.57EQUI0000000259 500032001/EU179 0.13 0.57 0.57EQUI0000000282 431032016/EU180 0.48 2.1 2.1EQUI0000000285 431032012/EU178 0.13 0.57 0.57EQUI0000000002 EU170 0 0 0EQUI0000000016 EU430 0.19 0.86 0.86EQUI0000000019 EU505 0.55 2.4 2.4EQUI0000000020 EU520 0.78 3.43 3.43EQUI0000000021 EU530 18.2 79.5 79.5EQUI0000000022 EU540 2.35 10.3 10.3EQUI0000000945 EU322 4.87 19.4 19.4

Parameter Desc Subject Item ID Subject Item Designation Potential (lbs/hr) Unrestricted Pot (tpy) Limited (tpy)EQUI0000000009 EU320 1.2 4.77 4.77EQUI0000000013 EU340 0 0 0EQUI0000000944 EU602 6.9 4.4 4.4EQUI0000000044 EU174 1.88 8.21 8.21EQUI0000000052 EU906 0 0 0EQUI0000000053 EU907 0 0 0EQUI0000000003 EU173 0 0 0FUGI0000000003 FS601 3.24 14.18 14.2STRU0000000020 SV173 0 0 0

Methyl ethyl ketone (MEK) EQUI0000000002 EU170 0 0 0EQUI0000000016 EU430 0 0 0EQUI0000000019 EU505 0 0 0EQUI0000000020 EU520 0 0 0EQUI0000000021 EU530 0 0 0EQUI0000000022 EU540 0 0 0EQUI0000000013 EU340 0 0 0EQUI0000000052 EU906 0 0 0EQUI0000000053 EU907 0 0 0STRU0000000020 SV173 0 0 0EQUI0000000241 532032004/EU326 0 0 0EQUI0000000242 532032002/EU325 0 0 0EQUI0000000255 512032005/EU301 0 0 0EQUI0000000259 500032001/EU179 0 0 0EQUI0000000282 431032016/EU180 0 0.01 0.01EQUI0000000285 431032012/EU178 0 0 0EQUI0000000002 EU170 0 0 0EQUI0000000016 EU430 0.18 0.79 0.79EQUI0000000019 EU505 0.01 0.02 0.02EQUI0000000020 EU520 0.01 0.03 0.03EQUI0000000021 EU530 0.03 0.15 0.15EQUI0000000022 EU540 0.72 3.15 3.15EQUI0000000945 EU322 0.01 0.05 0.05EQUI0000000009 EU320 0.03 0.13 0.13EQUI0000000013 EU340 0 0.01 0.01

Methyl isobutyl ketone (4‐Methyl‐2‐pentanone)

Parameter Desc Subject Item ID Subject Item Designation Potential (lbs/hr) Unrestricted Pot (tpy) Limited (tpy)EQUI0000000044 EU174 0.01 0.03 0.03EQUI0000000052 EU906 0 0 0EQUI0000000053 EU907 0 0 0EQUI0000000003 EU173 0 0 0STRU0000000020 SV173 0 0 0

Naphthalene EQUI0000000015 EU420 0 0 0EQUI0000000016 EU430 0 0.01 0.01EQUI0000000017 EU440 0 0 0EQUI0000000018 EU460 0 0 0EQUI0000000019 EU505 0.01 0.03 0.03EQUI0000000020 EU520 0.01 0.06 0.06EQUI0000000021 EU530 0.01 0.03 0.03EQUI0000000022 EU540 0.03 0.11 0.11EQUI0000000945 EU322 0.01 0.02 0.02EQUI0000000009 EU320 0.01 0.04 0.04EQUI0000000013 EU340 0.01 0.02 0.02

Nickel compounds EQUI0000000015 EU420 0 0 0EQUI0000000016 EU430 0 0 0EQUI0000000017 EU440 0 0 0EQUI0000000018 EU460 0 0 0EQUI0000000945 EU322 0 0 0EQUI0000000009 EU320 0 0.01 0.01EQUI0000000013 EU340 0 0 0

Nitrogen Oxides EQUI0000000015 EU420 79.6 349 349EQUI0000000016 EU430 100.2 438.88 438.88EQUI0000000017 EU440 18.7 81.7 81.7EQUI0000000018 EU460 10.3 44.9 44.9EQUI0000000945 EU322 2.19 8.75 8.75EQUI0000000024 EU903 0 0 0EQUI0000000009 EU320 110 481.8 481.8EQUI0000000013 EU340 34.9 153 153EQUI0000000941 EU918 0.93 0.23 0.23EQUI0000000942 EU919 6.7 1.67 1.67EQUI0000000943 EU920 5.68 1.42 1.42

Parameter Desc Subject Item ID Subject Item Designation Potential (lbs/hr) Unrestricted Pot (tpy) Limited (tpy)Nitrous Oxide EQUI0000000015 EU420 26.15 114.53 114.53

EQUI0000000016 EU430 934.21 4,092.00 4,092.00EQUI0000000017 EU440 24.15 107.33 107.33EQUI0000000018 EU460 13.47 58.99 58.99EQUI0000000009 EU320 212.72 848.84 848.84EQUI0000000941 EU918 0 0 0EQUI0000000942 EU919 0 0 0EQUI0000000943 EU920 0 0 0

o‐Cresol EQUI0000000044 EU174 1.06 4.65 4.65EQUI0000000044 EU174 0.56 2.44 2.44

Pentachlorophenol (PCP) EQUI0000000016 EU430 0 0 0Phenol EQUI0000000282 431032016/EU180 0.13 0.56 0.56

EQUI0000000002 EU170 0 0 0EQUI0000000016 EU430 0.01 0.03 0.03EQUI0000000019 EU505 0.1 0.45 0.45EQUI0000000020 EU520 0.15 0.64 0.64EQUI0000000021 EU530 0.11 0.48 0.48EQUI0000000022 EU540 0.44 1.93 1.93EQUI0000000945 EU322 0.04 0.16 0.16EQUI0000000009 EU320 0.91 3.63 3.63EQUI0000000013 EU340 0.1 0.46 0.46EQUI0000000044 EU174 0.01 0.04 0.04EQUI0000000003 EU173 0 0 0

Phosphorus EQUI0000000016 EU430 0.12 0.55 0.55EQUI0000000945 EU322 0 0.01 0.01EQUI0000000009 EU320 0.01 0.05 0.05EQUI0000000013 EU340 0.03 0.14 0.14

PM < 2.5 micron EQUI0000000015 EU420 2.97 12.99 12.99EQUI0000000016 EU430 11.7 854 51.25EQUI0000000017 EU440 2.78 12.17 12.17EQUI0000000018 EU460 1.53 6.69 6.69EQUI0000000019 EU505 0.54 2.37 2.37EQUI0000000020 EU520 0.47 2.05 2.05EQUI0000000021 EU530 0.66 2.89 2.89

Parameter Desc Subject Item ID Subject Item Designation Potential (lbs/hr) Unrestricted Pot (tpy) Limited (tpy)EQUI0000000022 EU540 2.29 10 10EQUI0000000945 EU322 7.3 200 32EQUI0000000024 EU903 0.65 2.85 2.85EQUI0000000009 EU320 19.2 1,400.00 84.1EQUI0000000013 EU340 12.7 348 55.63EQUI0000000940 EU917 2.9 12.7 12.7EQUI0000000944 EU602 22.2 14.18 14.18EQUI0000000941 EU918 0 0 0EQUI0000000942 EU919 0.48 0.12 0.12EQUI0000000943 EU920 0.02 0.01 0.01EQUI0000000049 EU350 0.74 1.5 1.5EQUI0000000012 EU902 0.97 0.51 0.51FUGI0000000004 FS905 0.19 0.26 0.26FUGI0000000005 FS703 0.46 0.55 0.55

PM < 10 micron EQUI0000000015 EU420 2.97 12.99 12.99EQUI0000000016 EU430 11.7 854 51.25EQUI0000000017 EU440 2.78 12.17 12.17EQUI0000000018 EU460 1.53 6.69 6.69EQUI0000000019 EU505 0.59 2.58 2.58EQUI0000000020 EU520 0.57 2.49 2.49EQUI0000000021 EU530 0.76 3.28 3.28EQUI0000000022 EU540 2.96 13 13EQUI0000000945 EU322 7.3 200 32EQUI0000000024 EU903 0.65 2.85 2.85EQUI0000000009 EU320 19.2 1,400.00 84.1EQUI0000000013 EU340 12.7 348 55.63EQUI0000000940 EU917 2.9 12.7 12.7EQUI0000000944 EU602 22.2 14.18 14.18EQUI0000000941 EU918 0 0 0EQUI0000000942 EU919 0.48 0.12 0.12EQUI0000000943 EU920 0.02 0.01 0.01EQUI0000000049 EU350 0.74 1.5 1.5EQUI0000000012 EU902 0.97 0.51 0.51FUGI0000000004 FS905 0.79 1.07 1.07

Parameter Desc Subject Item ID Subject Item Designation Potential (lbs/hr) Unrestricted Pot (tpy) Limited (tpy)FUGI0000000005 FS703 4.61 5.5 5.5

Polycyclic organic matter EQUI0000000015 EU420 0 0 0EQUI0000000017 EU440 0 0 0EQUI0000000009 EU320 0 0 0EQUI0000000013 EU340 0 0 0

Propionaldehyde EQUI0000000255 512032005/EU301 0 0 0EQUI0000000259 500032001/EU179 0 0 0EQUI0000000282 431032016/EU180 0 0.02 0.02EQUI0000000285 431032012/EU178 0 0 0EQUI0000000016 EU430 0.01 0.04 0.04EQUI0000000019 EU505 0.1 0.46 0.46EQUI0000000020 EU520 0.15 0.65 0.65EQUI0000000021 EU530 0.01 0.06 0.06EQUI0000000022 EU540 0.45 1.96 1.96EQUI0000000945 EU322 0.04 0.17 0.17EQUI0000000009 EU320 0.43 1.73 1.73EQUI0000000013 EU340 0.06 0.25 0.25EQUI0000000044 EU174 0.09 0.37 0.37EQUI0000000003 EU173 0 0 0

Selenium compounds EQUI0000000015 EU420 0 0 0EQUI0000000016 EU430 0 0 0EQUI0000000017 EU440 0 0 0EQUI0000000018 EU460 0 0 0EQUI0000000945 EU322 0 0 0EQUI0000000009 EU320 0 0 0EQUI0000000013 EU340 0 0 0

Styrene EQUI0000000242 532032002/EU325 0 0.01 0.01EQUI0000000255 512032005/EU301 0 0 0EQUI0000000259 500032001/EU179 0 0 0EQUI0000000282 431032016/EU180 0 0 0EQUI0000000285 431032012/EU178 0 0 0EQUI0000000002 EU170 0 0 0EQUI0000000016 EU430 0.01 0.03 0.03EQUI0000000019 EU505 0 0.02 0.02

Parameter Desc Subject Item ID Subject Item Designation Potential (lbs/hr) Unrestricted Pot (tpy) Limited (tpy)EQUI0000000020 EU520 0.01 0.03 0.03EQUI0000000021 EU530 0.03 0.14 0.14EQUI0000000022 EU540 0.02 0.09 0.09EQUI0000000945 EU322 0 0 0EQUI0000000009 EU320 0.01 0.02 0.02EQUI0000000013 EU340 0 0 0EQUI0000000044 EU174 0.01 0.06 0.06EQUI0000000052 EU906 0 0 0EQUI0000000053 EU907 0 0 0EQUI0000000003 EU173 0 0 0STRU0000000020 SV173 0 0 0EQUI0000000242 532032002/EU325 0.01 0.02 0.02EQUI0000000255 512032005/EU301 0.25 1.08 1.08EQUI0000000259 500032001/EU179 0.25 1.08 1.08EQUI0000000282 431032016/EU180 1.07 4.67 4.67EQUI0000000285 431032012/EU178 0.25 1.08 1.08EQUI0000000002 EU170 0 0 0EQUI0000000945 EU322 3.43 27.4 13.7EQUI0000000024 EU903 0.1 0.46 0.46EQUI0000000009 EU320 1.72 6.87 6.87EQUI0000000013 EU340 0.66 2.87 2.87EQUI0000000944 EU602 4.56 2.91 2.91EQUI0000000044 EU174 7.5 32.85 32.85EQUI0000000003 EU173 0 0 0FUGI0000000003 FS601 0 0 0STRU0000000020 SV173 0 0 0

Sulfur Dioxide EQUI0000000015 EU420 0.23 1.03 1.03EQUI0000000016 EU430 39.5 173 173EQUI0000000017 EU440 0.22 0.96 0.96EQUI0000000018 EU460 0.12 0.53 0.53EQUI0000000945 EU322 4.3 18.8 18.8EQUI0000000024 EU903 0 0 0EQUI0000000009 EU320 106.2 200 200EQUI0000000013 EU340 13.5 591 59.13

Sulfur ‐ Total Reduced including H2S

Parameter Desc Subject Item ID Subject Item Designation Potential (lbs/hr) Unrestricted Pot (tpy) Limited (tpy)EQUI0000000044 EU174 1.25 5.48 5.48EQUI0000000003 EU173 0 0 0STRU0000000020 SV173 0 0 0

Sulfuric Acid Mist EQUI0000000015 EU420 0 0 0EQUI0000000016 EU430 0 0 0EQUI0000000017 EU440 0 0 0EQUI0000000018 EU460 0 0 0EQUI0000000009 EU320 0 0 0EQUI0000000013 EU340 0 0 0STRU0000000020 SV173 0 0 0

TCDD ‐ TE EQUI0000000016 EU430 0 0 0EQUI0000000009 EU320 0 0 0EQUI0000000241 532032004/EU326 0 0 0EQUI0000000255 512032005/EU301 0 0 0EQUI0000000259 500032001/EU179 0 0 0EQUI0000000282 431032016/EU180 0 0 0EQUI0000000285 431032012/EU178 0 0 0EQUI0000000002 EU170 0 0 0EQUI0000000016 EU430 0.01 0.05 0.05EQUI0000000019 EU505 0.01 0.03 0.03EQUI0000000020 EU520 0.01 0.04 0.04EQUI0000000021 EU530 0.09 0.4 0.4EQUI0000000022 EU540 0.03 0.13 0.13EQUI0000000945 EU322 0 0 0EQUI0000000009 EU320 0 0.01 0.01EQUI0000000013 EU340 0.01 0.06 0.06EQUI0000000044 EU174 0.04 0.18 0.18EQUI0000000003 EU173 0 0 0

Toluene EQUI0000000241 532032004/EU326 0 0 0EQUI0000000242 532032002/EU325 0 0 0EQUI0000000255 512032005/EU301 0 0 0EQUI0000000259 500032001/EU179 0 0 0EQUI0000000282 431032016/EU180 0 0 0EQUI0000000285 431032012/EU178 0 0 0

Tetrachloroethylene (Perchloroethylene)

Parameter Desc Subject Item ID Subject Item Designation Potential (lbs/hr) Unrestricted Pot (tpy) Limited (tpy)EQUI0000000002 EU170 0 0 0EQUI0000000015 EU420 0 0.01 0.01EQUI0000000016 EU430 0 0.01 0.01EQUI0000000017 EU440 0 0.01 0.01EQUI0000000018 EU460 0 0 0EQUI0000000019 EU505 0 0.01 0.01EQUI0000000020 EU520 0 0.01 0.01EQUI0000000021 EU530 0.02 0.08 0.08EQUI0000000022 EU540 0.04 0.17 0.17EQUI0000000945 EU322 0 0.01 0.01EQUI0000000009 EU320 0.02 0.08 0.08EQUI0000000013 EU340 0.01 0.03 0.03EQUI0000000044 EU174 0.01 0.04 0.04EQUI0000000052 EU906 0 0 0EQUI0000000053 EU907 0 0 0EQUI0000000012 EU902 2.26 1.18 1.18EQUI0000000003 EU173 0 0 0STRU0000000020 SV173 0 0 0

Total Particulate Matter EQUI0000000015 EU420 2.97 12.99 12.99EQUI0000000016 EU430 13 2,850.00 56.94EQUI0000000017 EU440 2.78 12.17 12.17EQUI0000000018 EU460 1.53 6.69 6.69EQUI0000000019 EU505 0.64 2.82 2.82EQUI0000000020 EU520 0.65 2.83 2.83EQUI0000000021 EU530 8.84 3.68 3.68EQUI0000000022 EU540 3.55 15.6 15.6EQUI0000000945 EU322 7.3 533 32EQUI0000000024 EU903 0.65 2.85 2.85EQUI0000000009 EU320 27 118,000.00 118.26EQUI0000000013 EU340 12.7 927 55.63EQUI0000000940 EU917 3 13.14 13.14EQUI0000000944 EU602 22.2 14.18 14.18EQUI0000000941 EU918 0 0 0EQUI0000000942 EU919 0.48 0.12 0.12

Parameter Desc Subject Item ID Subject Item Designation Potential (lbs/hr) Unrestricted Pot (tpy) Limited (tpy)EQUI0000000943 EU920 0.02 0.01 0.01EQUI0000000049 EU350 0.11 0.22 0.22EQUI0000000012 EU902 0.97 0.51 0.51FUGI0000000004 FS905 3.94 5.34 5.34FUGI0000000005 FS703 16.2 19.3 19.3EQUI0000000015 EU420 0 0 0EQUI0000000016 EU430 0 0 0EQUI0000000017 EU440 0 0 0EQUI0000000018 EU460 0 0 0EQUI0000000009 EU320 0 0 0EQUI0000000013 EU340 0 0 0

Trichloroethylene (TCE) EQUI0000000255 512032005/EU301 0 0 0EQUI0000000282 431032016/EU180 0 0 0EQUI0000000285 431032012/EU178 0 0 0EQUI0000000002 EU170 0 0 0EQUI0000000016 EU430 0.01 0.04 0.04EQUI0000000019 EU505 0 0 0EQUI0000000020 EU520 0 0 0EQUI0000000021 EU530 0.06 0.25 0.25EQUI0000000022 EU540 0 0 0EQUI0000000945 EU322 0 0.01 0.01EQUI0000000009 EU320 0 0 0EQUI0000000013 EU340 0 0 0EQUI0000000044 EU174 0.05 0.23 0.23

Vinyl acetate (Acetic acid) EQUI0000000945 EU322 0 0.01 0.01Vinyl chloride (chloroethene) EQUI0000000016 EU430 0.01 0.03 0.03

EQUI0000000009 EU320 0 0 0Volatile Organic Compounds EQUI0000000241 532032004/EU326 0.02 0.07 0.07

EQUI0000000242 532032002/EU325 0.77 3.37 3.37EQUI0000000255 512032005/EU301 0.54 2.34 2.34EQUI0000000259 500032001/EU179 0.54 2.34 2.34EQUI0000000282 431032016/EU180 9.68 42.4 42.4EQUI0000000285 431032012/EU178 0.54 2.34 2.34EQUI0000000002 EU170 0 0 0

Total Polycyclic aromatic hydrocarbons

Parameter Desc Subject Item ID Subject Item Designation Potential (lbs/hr) Unrestricted Pot (tpy) Limited (tpy)EQUI0000000015 EU420 2.15 9.41 9.41EQUI0000000016 EU430 40.2 176 176EQUI0000000017 EU440 3.36 14.7 14.7EQUI0000000018 EU460 1.85 8.08 8.08EQUI0000000019 EU505 0.97 4.23 4.23EQUI0000000020 EU520 1.38 6.04 6.04EQUI0000000021 EU530 1.04 4.53 4.53EQUI0000000022 EU540 13.6 59.7 59.7EQUI0000000945 EU322 5.98 23.9 23.9EQUI0000000024 EU903 3.5 15.3 15.3EQUI0000000009 EU320 31.3 137.09 137.09EQUI0000000013 EU340 11.4 49.9 49.9EQUI0000000944 EU602 29.3 18.68 18.68EQUI0000000941 EU918 0.13 0.03 0.03EQUI0000000942 EU919 0.53 0.13 0.13EQUI0000000943 EU920 0.53 0.13 0.13EQUI0000000044 EU174 12.5 54.75 54.75EQUI0000000052 EU906 1.61 7.07 7.07EQUI0000000053 EU907 1.61 7.07 7.07EQUI0000000012 EU902 22.5 11.75 11.75EQUI0000000025 EU909 2.31 10.12 10.12EQUI0000000003 EU173 0 0 0FUGI0000000003 FS601 3.24 14.18 14.18STRU0000000020 SV173 0 0 0

Xylene (m‐) EQUI0000000242 532032002/EU325 0 0.01 0.01EQUI0000000255 512032005/EU301 0 0 0EQUI0000000259 500032001/EU179 0 0 0EQUI0000000282 431032016/EU180 0 0 0EQUI0000000002 EU170 0 0 0EQUI0000000016 EU430 0 0 0EQUI0000000019 EU505 0.06 0.01 0.01EQUI0000000020 EU520 0.02 0.08 0.08EQUI0000000021 EU530 0.11 0.03 0.03EQUI0000000022 EU540 0.05 0.24 0.24

Parameter Desc Subject Item ID Subject Item Designation Potential (lbs/hr) Unrestricted Pot (tpy) Limited (tpy)EQUI0000000945 EU322 0 0.02 0.02EQUI0000000009 EU320 0.03 0.17 0.17EQUI0000000013 EU340 0 0.02 0.02EQUI0000000044 EU174 0.01 0.04 0.04EQUI0000000003 EU173 0 0 0STRU0000000020 SV173 0 0 0

Xylene (o‐) EQUI0000000241 532032004/EU326 0 0 0EQUI0000000242 532032002/EU325 0 0 0EQUI0000000255 512032005/EU301 0 0 0EQUI0000000259 500032001/EU179 0 0 0EQUI0000000282 431032016/EU180 0 0 0EQUI0000000285 431032012/EU178 0 0 0EQUI0000000002 EU170 0 0 0EQUI0000000016 EU430 0 0 0EQUI0000000019 EU505 0.02 0.09 0.09EQUI0000000020 EU520 0.03 0.12 0.12EQUI0000000021 EU530 0.02 0.1 0.1EQUI0000000022 EU540 0.08 0.37 0.37EQUI0000000945 EU322 0.01 0.03 0.03EQUI0000000009 EU320 0.03 0.13 0.13EQUI0000000013 EU340 0 0.02 0.02EQUI0000000044 EU174 0.01 0.04 0.04EQUI0000000003 EU173 0 0 0STRU0000000020 SV173 0 0 0

Xylene (p‐) EQUI0000000242 532032002/EU325 0 0.01 0.01EQUI0000000255 512032005/EU301 0 0 0EQUI0000000259 500032001/EU179 0 0 0EQUI0000000282 431032016/EU180 0 0 0EQUI0000000285 431032012/EU178 0 0 0EQUI0000000002 EU170 0 0 0EQUI0000000016 EU430 0 0 0EQUI0000000019 EU505 0.06 0.01 0.01EQUI0000000020 EU520 0.02 0.08 0.08EQUI0000000021 EU530 0.11 0.03 0.03

Parameter Desc Subject Item ID Subject Item Designation Potential (lbs/hr) Unrestricted Pot (tpy) Limited (tpy)EQUI0000000022 EU540 0.05 0.24 0.24EQUI0000000945 EU322 0 0.02 0.02EQUI0000000009 EU320 0.03 0.17 0.17EQUI0000000013 EU340 0 0.02 0.02EQUI0000000044 EU174 0.01 0.04 0.04EQUI0000000003 EU173 0 0 0STRU0000000020 SV173 0 0 0

Xylenes, Total EQUI0000000255 512032005/EU301 0 0 0EQUI0000000259 500032001/EU179 0 0 0EQUI0000000282 431032016/EU180 0 0 0EQUI0000000285 431032012/EU178 0 0 0EQUI0000000016 EU430 0 0.01 0.01EQUI0000000019 EU505 0 0.01 0.01EQUI0000000020 EU520 0 0.01 0.01EQUI0000000021 EU530 0 0.01 0.01EQUI0000000022 EU540 0.01 0.04 0.04EQUI0000000945 EU322 0 0.01 0.01EQUI0000000009 EU320 0.03 0.13 0.13EQUI0000000013 EU340 0.01 0.04 0.04EQUI0000000044 EU174 0.02 0.11 0.11EQUI0000000052 EU906 0 0 0EQUI0000000053 EU907 0 0 0EQUI0000000012 EU902 8.55 4.46 4.46

Totals PM PM10 PM2.5 SO2 Nox CO VOC CO2e Single HAP

Total HAPs

TRS

EQUI 44 0.000 0.000 0.000 5.475 0.000 0.000 54.750 0.000 8.213 22.798 32.850EQUI 285 0.000 0.000 0.000 0.000 0.000 0.000 2.343 0.000 0.569 0.632 1.078EQUI 259 0.000 0.000 0.000 0.000 0.000 0.000 2.343 0.000 0.569 0.632 1.078EQUI 282 0.000 0.000 0.000 0.000 0.000 0.000 42.398 0.000 2.102 2.787 4.671EQUI 255 0.000 0.000 0.000 0.000 0.000 0.000 2.343 0.000 0.569 0.632 1.078EQUI 9 118.260 84.096 84.096 200.000 481.800 2289.000 137.094 641396.988 4.774 30.841 6.869EQUI 945 31.974 31.974 31.974 18.834 8.752 2.179 23.868 0.000 19.439 20.524 13.711EQUI 242 0.000 0.000 0.000 0.000 0.000 0.000 3.373 0.000 6.643 6.666 0.023EQUI 241 0.000 0.000 0.000 0.000 0.000 0.000 0.072 0.000 0.056 0.063 0.000EQUI 13 55.626 55.626 55.626 59.130 152.862 103.806 49.932 35910.490 0.000 2.022 2.867EQUI 49 0.215 1.502 1.502 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000EQUI 15 12.987 12.987 12.987 1.025 348.648 143.562 9.410 204127.979 0.000 3.225 0.000EQUI 16 56.940 51.246 51.246 173.010 438.876 876.000 176.076 362548.342 0.859 89.576 0.000EQUI 17 12.173 12.173 12.173 0.961 81.687 147.037 14.704 191305.870 0.000 3.022 0.000EQUI 18 6.691 6.691 6.691 0.528 44.895 147.168 8.081 105141.296 0.000 1.661 0.000EQUI 19 2.816 2.576 2.367 0.000 0.000 0.000 4.231 0.000 2.398 4.373 0.000EQUI 20 2.831 2.491 2.050 0.000 0.000 0.000 6.044 0.000 3.425 7.875 0.000EQUI 21 3.685 3.277 2.887 0.000 0.000 0.000 4.533 0.000 79.497 89.576 0.000EQUI 22 15.571 12.968 10.014 0.000 0.000 0.000 59.656 0.000 10.275 30.686 0.000EQUI 944 14.178 14.178 14.178 0.000 0.000 0.000 18.681 0.000 4.401 5.183 2.907EQUI 12 0.506 0.506 0.506 0.000 0.000 0.000 11.745 0.000 0.000 6.588 0.000EQUI 24 2.847 2.847 2.847 0.000 0.000 0.000 15.330 0.000 0.000 0.000 0.456EQUI 52 0.000 0.000 0.000 0.000 0.000 0.000 7.073 0.000 0.000 0.226 0.000EQUI 53 0.000 0.000 0.000 0.000 0.000 0.000 7.073 0.000 0.000 0.226 0.000EQUI 25 0.000 0.000 0.000 0.000 0.000 0.000 10.118 0.000 0.000 0.000 0.000EQUI 940 13.140 12.702 12.702 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000EQUI 941 0.001 0.001 0.001 0.000 0.231 0.545 0.032 8.525 0.000 0.000 0.000EQUI 942 0.119 0.119 0.119 0.111 1.674 0.361 0.133 62.312 0.000 0.000 0.000EQUI 943 0.006 0.006 0.006 0.000 1.421 3.346 0.199 52.369 0.000 0.000 0.000COMG 6 0.000 0.000 0.000 115.000 0.000 0.000 1.944 0.000 0.205 0.375 3.352COMG 8 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 3.833 3.931 2.023COMG 11 0.000 0.000 0.000 0.000 0.000 0.000 0.055 0.000 0.029 0.834 0.000COMG 12 0.000 0.000 0.000 10.056 0.000 209.616 13.923 0.000 31.054 44.588 2.640Totals (SIs, COMGs) 350.57 307.97 303.97 584.13 1560.85 3922.62 687.56 1540554 178.91 379.54 75.60Totals (tons/yr) 375.19 314.53 304.78 584.13 1560.85 3922.62 701.74 1540554.17 193.09 393.95 75.60

Fugitive Sources PM PM10 PM2.5 VOC HAPs Total HAPs

TRS

FUGI 3 14.180 14.180 14.405 0.000FUGI 5 19.280 5.496 0.550FUGI 4 5.341 1.068 0.262Fugitive totals 24.62 6.56 0.81 14.18 14.18 14.40 0.00

Attachment 2: BLS Limit Increase - PSD Permit Applicability Calculations


C:\Users\bkruege\Desktop\Copy of 443 - CALCULATIONS FOR APPLICATION RECEIVED 4-18-16.XLSX - - BOLSON1 - BERT BROWN - PUBLIC.xlsxEmit Increase from BLS


Boise White Paper, LLC - International Falls, MNBlack Liquor Solids Limit IncreasePSD Permit Applicability Calculations

40,982 tons BLS/month BLS Limit491,778 tons BLS/year 5%

42,294 tons BLS/month increase507,530 tons BLS/year

44,200 tons BLS/month530,400 tons BLS/year

46,410 tons BLS/month556,920 tons BLS/year

Maximum Monthly (01/2015) 45,720 tons BLS/monthMaximum Month for 1 year 548,640 tons BLS/year

BLS Accommodated Production (Existing Limit) 530,400 tons BLS/year

2013Actual Emissions[2]

(tons/year)


(tons/year)


(tons/year)Time Period

(24-months)[4]

Baseline Actual Emissions

(tons/year)Future Production

(ton/year)

Future Emission Factor

(lb/prod ton)[5] Source of future emission factor

Projected Actual Emissions

(tons/year)

Accommodated Production(tons/year)

2015Emission Factor

(lb/prod ton)

Accommodated Emissions

(tons/year)

DGE(Accommodated -

BAE)(tons/year)[7]

Emission IncreasePAE - BAE - DGE

(tons/year)[8]

PSD Threshold

(tons/year) GREATER

than PSD?

Reasonable Possibility

52.21(r)(6)(vi)(a)

Reasonable Possibility

52.21(r)(6)(vi)(b)

EU 320 Recovery Furnace NOx 322.90 304.50 316.10 1/2013 - 12/2014 313.70 556,920 1.25 CEMS 10/1/15-12/31/15 346.82 530,400 1.25 331.50 17.80 15.32 --- --- --- ---EU 322 Smelt Dissolving Tank NOx 0.91 0.93 0.96 1/2013 - 12/2014 0.92 556,920 0.0038 September 2006 Stack Test 1.06 530,400 0.0038 1.01 0.09 0.05 --- --- --- ---TOTAL --- NOx --- --- --- --- --- --- --- --- --- --- --- --- --- 15.37 40 no no yesEU 320 Recovery Furnace CO 709.90 929.40 1,039.61 1/2009-12/2010 1,208.00 556,920 4.45 CEMS 10/1/15-12/31/15 1,239.92 530,400 4.10 1,087.32 0.00 31.92 --- --- --- ---EU 322 Smelt Dissolving Tank CO 1.97 2.02 2.09 1/2009-12/2010 1.92 556,920 8.22E-03 NCASI Emission Factor (TB 884) 2.29 530,400 8.22E-03 2.18 0.26 0.11 --- --- --- ---TOTAL --- CO --- --- --- --- --- --- --- --- --- --- --- --- --- 32.03 100 no no noEU 320 Recovery Furnace PM (Fil + Cond) 32.80 33.62 34.67 1/2014 - 12/2015 34.15 556,920 0.1367 July 2011 Stack Test 38.08 530,400 0.1400 37.13 2.98 0.95 --- --- --- ---EU 322 Smelt Dissolving Tank PM (Fil + Cond) 20.55 21.08 21.72 1/2014 - 12/2015 21.40 556,920 0.086 July 2011 Stack Test 23.95 530,400 0.086 22.81 1.41 1.14 --- --- --- ---TOTAL --- PM (Fil + Cond) --- --- --- --- --- --- --- --- --- --- --- --- --- 2.09 25 no no noEU 320 Recovery Furnace PM10 (Fil + Cond) 24.60 25.21 26.00 1/2014 - 12/2015 25.61 556,920 0.1026 July 2011 Stack Test 28.56 530,400 0.1000 26.52 0.91 2.04 --- --- --- ---EU 322 Smelt Dissolving Tank PM10 (Fil + Cond) 20.55 21.08 21.72 1/2014 - 12/2015 21.40 556,920 0.086 July 2011 Stack Test 23.95 530,400 0.086 22.81 1.41 1.14 --- --- --- ---TOTAL --- PM10 (Fil + Cond) --- --- --- --- --- --- --- --- --- --- --- --- --- 3.18 25 no no noEU 320 Recovery Furnace PM2.5 (Fil + Cond) 24.60 25.21 26.00 1/2014 - 12/2015 25.61 556,920 0.1026 July 2011 Stack Test 28.56 530,400 0.1000 26.52 0.91 2.04 --- --- --- ---EU 322 Smelt Dissolving Tank PM2.5 (Fil + Cond) 20.55 21.08 21.72 1/2014 - 12/2015 21.40 556,920 0.086 July 2011 Stack Test 23.95 530,400 0.086 22.81 1.41 1.14 --- --- --- ---TOTAL --- PM2.5 (Fil + Cond) --- --- --- --- --- --- --- --- --- --- --- --- --- 3.18 10 no no yesEU 320 Recovery Furnace SO2 0.00 0.00 0.00 1/2014 - 12/2015 0.00 556,920 0.000 September 2006 Stack Test 0.00 530,400 0.00 0.00 0.00 0.00 --- --- --- ---EU 322 Smelt Dissolving Tank SO2 0.00 0.00 0.00 1/2014 - 12/2015 0.00 556,920 0.000 September 2006 Stack Test 0.00 530,400 0.00 0.00 0.00 0.00 --- --- --- ---TOTAL --- SO2 --- --- --- --- --- --- --- --- --- --- --- --- --- 0.00 10 no no noEU 320 Recovery Furnace VOC 3.62 3.71 3.83 1/2014 - 12/2015 3.77 556,920 0.0151 July 2011 Stack Test 4.20 530,400 0.0150 3.98 0.21 0.23 --- --- --- ---EU 322 Smelt Dissolving Tank VOC 0.91 0.93 0.96 1/2014 - 12/2015 0.95 556,920 0.0038 September 2006 Stack Test 1.06 530,400 0.0038 1.01 0.06 0.05 --- --- --- ---TOTAL --- VOC --- --- --- --- --- --- --- --- --- --- --- --- --- 0.28 10 no no noEU 320 Recovery Furnace Lead 0.0507 0.0519 0.0536 1/2014 - 12/2015 0.05272 556,920 2.11E-04 2015 Emission Factor 0.0588 530,400 2.11E-04 0.06 0.003237 0.00280 --- --- --- ---EU 322 Smelt Dissolving Tank Lead 0.000166 0.000170 0.000175 1/2014 - 12/2015 0.000172 556,920 7.00E-07 2015 Emission Factor 0.000195 530,400 7.00E-07 0.00 0.000013 0.00001 --- --- --- ---TOTAL --- Lead --- --- --- --- --- --- --- --- --- --- --- --- --- 0.00281 10 no no noEU 320 Recovery Furnace Flourides NA NA NA NA NA 556,920 NA NA NA 530,400 NA NA NA NA --- --- --- ---EU 322 Smelt Dissolving Tank Flourides NA NA NA NA NA 556,920 NA NA NA 530,400 NA NA NA NA --- --- --- ---TOTAL --- Flourides --- --- --- --- --- --- --- --- --- --- --- --- --- 0.00 10 no no noEU 320 Recovery Furnace Sulfuric Acid (mist) 1.98 2.03 2.10 1/2014 - 12/2015 2.07 556,920 8.25E-03 NCASI Emission Factor 2.30 530,400 8.25E-03 2.19 0.12 0.11 --- --- --- ---EU 322 Smelt Dissolving Tank Sulfuric Acid (mist) NA NA NA 1/2014 - 12/2015 NA 556,920 NA NA NA 530,400 NA NA NA NA --- --- --- ---TOTAL --- Sulfuric Acid (mist) --- --- --- --- --- --- --- --- --- --- --- --- --- 0.11 10 no no noEU 320 Recovery Furnace H2S[9] 2.62 2.25 2.43 1/2014 - 12/2015 2.34 556,920 0.0096 2015 TRS CEMS Annual Average 2.67 530,400 0.0100 2.65 0.31 0.02 --- --- --- ---

EU 322 Smelt Dissolving Tank H2S[9] 0.94 0.96 0.99 1/2014 - 12/2015 0.98 556,920 0.004 2015 TRS CEMS Annual Average 1.09 530,400 0.004 1.06 0.08 0.03 --- --- --- ---TOTAL --- H2S[9] --- --- --- --- --- --- --- --- --- --- --- --- --- 0.04 10 no no noEU 320 Recovery Furnace TRS 2.62 2.25 2.43 1/2014 - 12/2015 2.34 556,920 0.0096 2015 TRS CEMS Annual Average 2.67 530,400 0.0100 2.65 0.31 0.02 --- --- --- ---EU 322 Smelt Dissolving Tank TRS 0.94 0.96 0.99 1/2014 - 12/2015 0.98 556,920 0.004 2015 TRS CEMS Annual Average 1.09 530,400 0.004 1.06 0.08 0.03 --- --- --- ---TOTAL --- TRS --- --- --- --- --- --- --- --- --- --- --- --- --- 0.04 10 no no noEU 320 Recovery Furnace TRS Compounds[10] 2.62 2.25 2.43 1/2014 - 12/2015 2.34 556,920 0.0096 2015 TRS CEMS Annual Average 2.67 530,400 0.0100 2.65 0.31 0.02 --- --- --- ---

EU 322 Smelt Dissolving Tank TRS Compounds[10] 0.94 0.96 0.99 1/2014 - 12/2015 0.98 556,920 0.004 2015 TRS CEMS Annual Average 1.09 530,400 0.004 1.06 0.08 0.03 --- --- --- ---TOTAL --- TRS Compounds[10] --- --- --- --- --- --- --- --- --- --- --- --- --- 0.04 10 no no noEU 320 Recovery Furnace CO2 577,226.01 611,089.77 598,546.70 1/2014 - 12/2015 604,818.23 556,920 2358.7 2015 Emit Factor Calculation[11] 656,803.60 530,400 2358.7 625,527.24 20,709.01 31,276.36 --- --- --- ---

EU 322 Smelt Dissolving Tank CO2 --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- ------ CO2 --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- ---

EU 320 Recovery Furnace CH4 12.13 12.35 12.13 1/2014 - 12/2015 12.24 556,920 0.0478 2015 Emit Factor Calculation[11] 13.31 530,400 0.0478 12.68 0.44 0.63 --- --- --- ---

EU 322 Smelt Dissolving Tank CH4 --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- ------ CH4 --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- ---

EU 320 Recovery Furnace N2O 2.54 2.76 2.65 1/2014 - 12/2015 2.70 556,920 0.0104 2015 Emit Factor Calculation[11] 2.90 530,400 0.0104 2.76 0.06 0.14 --- --- --- ---

EU 322 Smelt Dissolving Tank N2O --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- ------ N2O --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- ---

EU 320 Recovery Furnace CO2e 578,284.70 612,219.60 599,638.20 1/2014 - 12/2015 605,928.90 --- --- CO2 + CH4 + N2O with Global Warming Potential[11]

657,999.36 530,400 CO2 + CH4 + N2O with Global

Warming Potential[9]

626,666.06 20,737.16 31,333.30 --- --- --- ---

EU 322 Smelt Dissolving Tank CO2e --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- --- ------ CO2e --- --- --- --- --- --- --- --- --- --- --- --- --- 31,333.30 75000 no no yes

[1]

[2]

[3]

[4]

[5]

[6]

[7]

[8]

[9]

[10]

[11] CO2e Baseline and Emission Factor Calculations

2015 Emit FactorMetric Ton Ton Metric Ton Ton Metric Ton Ton lb/ton BLS

CO2 1 523,656.00 577,226.01 554,377.00 611,089.77 542,998.00 598,546.70 2358.7CH4 25 11.00 12.13 11.20 12.35 11.00 12.13 0.0478N2O 298 2.30 2.54 2.50 2.76 2.40 2.65 0.0104CO2e --- 524,616.4 578,284.7 555,402.0 612,219.6 543,988.2 599,638.2 2363

2015 production = 507,530 tons BLS

Per discussion with the National Council for Air and Stream Improvement (NCASI), TRS compounds emitted by EU 320 and 322 mainly include hydrogen sulphide (H2S), methyl mercaptan, dimethyl sulphide, and dimethyl disulphide. Carbonyl sulfide and carbon disulfide may be present, but only in trace quantities. Therefore, TRS is assumed to be equal to TRS compounds.

H2S emissions assumed to be equal to TRS emissions

Reasonable Possibility Determination

Source Pollutant

Comparison Only BAE PAE PSD Comparison

DGE calculated with "Accommodated Production" and 2015 emission factors

DGE cannot be less than 0

Emissions increase cannot be less than 0

DGE[6]

Past production rates are from emission inventory dataFuture production rate for BLS is the proposed BLS limitAccommodated production rate for BLS is existing BLS limitAir Emission Inventory data from 2013 and 2014

2015Recovery Furnace

Global Warming Potential

2013 2014

Air Emission Inventory data from 2015

The Time period for the BAE must be the same for each emission unit but each pollutant can have a different baseline period. For example, the NOx baseline could be "Feb 12 - Jan 14" for both emission units and "Apr 13 - Mar 15" for CO. But both EU 320 and EU 322 must use the same baseline for each of them. If monthly data was not available, we used 2013-2014 emission inventory data.

Future emission factors based on recent CEMS data and stack tests at anticipated production rates. Site specific emission rates are an accurate representation of actual emission rates versus AP-42 or standard emission factors.

Existing BLS Limit

Revised: 3/25/2016

Production Rates[1]

BLS

2014 BLS Actual

2015 BLS Actual

Future BLS Production

Page 2 of 2

Alternate Format GI-07 SpreadsheetFacility Emissions Summary

Air Quality Permit ProgramDoc Type: Permit Application

7100002 1b) Agency Interest ID No.: 102A

2) Facility Name: Boise White Paper, LLC

Emissions by Source Table

3c) 3d) 3f) 3c) 3d) 3f) 3c) 3d) 3f)

Pollutant Name CAS #Lbs per

HrUnc tpy

Limited tpy

Actual tpy Pollutant Name CAS #

Lbs per Hr

Unc tpy

Limited tpy

Actual tpy Pollutant Name CAS #

Lbs per Hr

Unc tpy

Limited tpy

Actual tpy

Carbon Monoxide 538.00 2,356.44 2,289.00 1,039.61 Carbon Monoxide 0.55 2.29 2.29 2.09

Nitrogen Oxides 110.00 481.80 481.80 316.10 Nitrogen Oxides 2.19 9.61 9.19 0.96

PM - Total 27.00 1.18E+05 118.26 34.67 PM - Total 7.30 639.48 31.97 21.72

PM10 - Total 19.20 8.41E+04 84.10 26.00 PM10 - Total 7.30 639.48 31.97 21.72

PM2.5 - Total 19.20 8.41E+04 84.10 26.00 PM2.5 - Total 7.30 639.48 31.97 21.72

Sulfur Dioxide 106.20 465.16 200.00 0.00 Sulfur Dioxide 4.30 18.83 18.83 0.00

VOCs as C 31.30 137.09 137.09 3.83 VOCs as C 4.30 18.83 18.83 0.96

CO2 160438.74 702721.66 702721.66 598546.70 CO2 --- --- --- ---

CH4 3.23 14.14 14.14 12.13 CH4 --- --- --- ---

N2O 0.71 3.13 3.13 2.65 N2O --- --- --- ---

CO2e 160732.18 704006.96 704006.96 599638.20 CO2e --- --- --- ---

5)

1a) AQ Facility ID No.:

3a) Delta ID No.:

3e) Potential 3e) Potential

3a) Delta ID No.:

3b) Tempo SI ID No.:

You may use and submit this spreadsheet in place of Form GI-07. Follow the instructions for Form GI-07 to complete this spreadsheet. This spreadsheet can be copied into a tab for your emissions spreadsheet and must be submitted on a CD with your application. If you need to provide emissions information for more emissions units, add more sets of columns (3a through 3f) to the right as needed in the Emissions by Source table. If you need to provide information for more pollutants, add rows as needed.


3e) Potential

320 3a) Delta ID No.: 322


Application is being submitted on paper, and editable calculation spreadsheet(s) are included on an enclosed CD.

Application is being submitted on a compact disc (CD), and the editable calculation spreadsheet(s) are included on the CD.

Attachment 3: Subject Item Inventory and Facility Requirements


Subject Item Category Subject Item ID SI Designation and Description Relationship

Related Subject Item ID Related Subject Item Type Description

Equipment EQUI71EU247Acid Sewer Vent ‐ Bleaching Equipment is controlled by TREA13 001‐Wet Scrubber ‐ High Efficiency

sends to STRU75 Stack/Vent

Equipment EQUI936EU225CLO2 Tower Seal Tank ‐ Bleaching Equipment is controlled by TREA12 001‐Wet Scrubber ‐ High Efficiency


Equipment EQUI937EU220ClO2 Generator ‐ Bleaching Equipment is controlled by TREA12 001‐Wet Scrubber ‐ High Efficiency


Equipment EQUI66EU242D/C Blend Chest ‐ Bleaching Equipment is controlled by TREA13 001‐Wet Scrubber ‐ High Efficiency


Equipment EQUI2EU170Blow Heat Accumulator ‐ Other Emission Unit sends to STRU123 Stack/Vent


Equipment EQUI15EU420Boiler #1 ‐ Boiler includes TREA18 099‐Other

sends to EQUI74 Data Acquisition System



Equipment EQUI16EU430Boiler #2 ‐ Boiler includes TREA19 099‐Other

is controlled by TREA5 010‐Electrostatic Precipitator ‐ High Efficiency

is controlled by TREA10 008‐Centrifugal Collector ‐ Medium Efficiency




Equipment EQUI17EU440Boiler #3 ‐ Boiler is controlled by TREA20 099‐Other



Equipment EQUI18EU460Boiler #9 ‐ Boiler is controlled by TREA22 099‐Other



Equipment EQUI32EU120Turpentine Relief Condenser dig. 1‐4 ‐ Other Emission Unit is controlled by TREA4 008‐Centrifugal Collector ‐ Medium Efficiency



is controlled by TREA15 001‐Wet Scrubber ‐ High Efficiency

is controlled by TREA16 099‐Other
















Equipment EQUI33EU125Turpentine Relief Condenser dig. 5‐8 ‐ Other Emission Unit is controlled by TREA4 008‐Centrifugal Collector ‐ Medium Efficiency




















Equipment EQUI36EU140Blow Heat Secondary Condenser ‐ Other Emission Unit is controlled by TREA4 008‐Centrifugal Collector ‐ Medium Efficiency




















Equipment EQUI60EU227Barametric Condenser ‐ Bleaching Equipment is controlled by TREA12 001‐Wet Scrubber ‐ High Efficiency


Equipment EQUI78MR916Lime Kiln TRS CEM ‐ Continuous Emission Monitor sends to EQUI74 Data Acquisition System

Equipment EQUI86MR911Recovery Furnace NOx CEM ‐ Continuous Emission monitors EQUI9 Furnace


Equipment EQUI87MR912Recovery Furnace TRS CEM ‐ Continuous Emission Monitor monitors EQUI9 Furnace


Equipment EQUI88MR913Recovery Furnace CO CEM ‐ Continuous Emission Monitor monitors EQUI9 Furnace


Equipment EQUI90MR915Boiler 2 CO CEM ‐ Continuous Emission Monitor monitors EQUI16 Boiler


Equipment EQUI109MR421Boiler 1 O2 CEM ‐ Continuous Emission Monitor monitors EQUI15 Boiler


Equipment EQUI110MR420Boiler 1 NOx CEM ‐ Continuous Emission Monitor monitors EQUI15 Boiler




Equipment EQUI124MR325Recovery Furnace O2 CEM ‐ Continuous Emission Monitor monitors EQUI9 Furnace


Equipment EQUI125MR327Lime Kiln O2 CEM ‐ Continuous Emission Monitor monitors EQUI13 Kiln


Equipment EQUI128MR440Boiler 3 NOX CEM ‐ Continuous Emission Monitor monitors EQUI17 Boiler






Equipment EQUI136MR460Boiler 9 NOX CEM ‐ Continuous Emission Monitor monitors EQUI18 Boiler


Equipment EQUI949 Boiler 2 NOX & SO2 CEM monitors EQUI16 Boiler


Equipment EQUI79MR320Recovery Furnace Opacity COM ‐ Continuous Opacity monitors EQUI9 Furnace


Equipment EQUI80MR432Boiler 2 Opacity COM ‐ Continuous Opacity Monitor monitors EQUI16 Boiler


Equipment EQUI19EU505No. 2 Paper Machine ‐ Other Emission Unit sends to STRU31 Stack/Vent










































Equipment EQUI31EU110Turpentine Decanter ‐ Decanting Equipment is controlled by TREA4 008‐Centrifugal Collector ‐ Medium Efficiency




















Equipment EQUI34EU130Pre‐evaporator Hotwell ‐ Other Emission Unit is controlled by TREA4 008‐Centrifugal Collector ‐ Medium Efficiency




















Equipment EQUI37EU309Evaporator Hotwell ‐ Other Emission Unit is controlled by TREA4 008‐Centrifugal Collector ‐ Medium Efficiency




















Equipment EQUI945EU322Smelt Dissolving Tank is controlled by TREA2 053‐Venturi Scrubber

is controlled by TREA3 053‐Venturi Scrubber


Equipment EQUI24EU903Sludge Dryer ‐ Other Emission Unit is controlled by TREA18 099‐Other




is controlled by TREA26 052‐Spray Tower





Equipment EQUI9EU320Recovery Furnace ‐Furnace includes TREA17 099‐Other




Equipment EQUI67EU243D‐Mixer Sample Pot. ‐ Bleaching Equipment is controlled by TREA13 001‐Wet Scrubber ‐ High Efficiency


Equipment EQUI13EU340Lime Kiln ‐ Kiln includes TREA16 099‐Other



is monitored by EQUI78 Continuous Emission Monitor








Equipment EQUI57EU224Sewer Vent (L8) ‐ Bleaching Equipment is controlled by TREA12 001‐Wet Scrubber ‐ High Efficiency


Equipment EQUI61EU228Saltcake Filter ‐ Bleaching Equipment is controlled by TREA12 001‐Wet Scrubber ‐ High Efficiency


Equipment EQUI62EU229Saltcake Hydroclone ‐ Bleaching Equipment is controlled by TREA12 001‐Wet Scrubber ‐ High Efficiency


Equipment EQUI63EU230Anti‐Siphon Vent ‐ Bleaching Equipment is controlled by TREA12 001‐Wet Scrubber ‐ High Efficiency


Equipment EQUI64EU240D/C Tower ‐ Bleaching Equipment is controlled by TREA13 001‐Wet Scrubber ‐ High Efficiency


Equipment EQUI65EU241D Tower ‐ Bleaching Equipment is controlled by TREA13 001‐Wet Scrubber ‐ High Efficiency


Equipment EQUI938EU910Turpentine Water Pad Tank is controlled by TREA4 008‐Centrifugal Collector ‐ Medium Efficiency













Equipment EQUI939EU916Sluice Bowl is controlled by TREA1 010‐Electrostatic Precipitator ‐ High Efficiency




Equipment EQUI940EU917Intermediate Chip Cyclone sends to STRU82 Stack/Vent

Equipment EQUI944EU602Wastewater Treatment Plant Cooling Tower sends to STRU72 Stack/Vent

Equipment EQUI950EU324Hopper Flush Tank is controlled by TREA1 010‐Electrostatic Precipitator ‐ High Efficiency




Equipment EQUI951EU360Rapid Drain Tank is controlled by TREA1 010‐Electrostatic Precipitator ‐ High Efficiency





Equipment EQUI952EU246EO Filt. Tank is controlled by TREA13 001‐Wet Scrubber ‐ High Efficiency


Equipment EQUI953EU226Saltcake Mix Tank is controlled by TREA12 001‐Wet Scrubber ‐ High Efficiency


Equipment EQUI954532032004/EU326Green Liquor Storage Tank sends to STRU142 Stack/Vent

Equipment EQUI955532032002/EU325Green Liquor Clarifier sends to STRU141 Stack/Vent

Equipment EQUI956EU323Precipitator Saltcake Mix Tank is controlled by TREA1 010‐Electrostatic Precipitator ‐ High Efficiency




Equipment EQUI957512032011/EU30355% BLS Tank is controlled by TREA1 010‐Electrostatic Precipitator ‐ High Efficiency









Equipment EQUI958512032010/EU905HL Swing Tank is controlled by TREA1 010‐Electrostatic Precipitator ‐ High Efficiency






Equipment EQUI959EU30772% BLS Tank is controlled by TREA1 010‐Electrostatic Precipitator ‐ High Efficiency









Equipment EQUI960512032005/EU30118% Liquor Tank sends to STRU132 Stack/Vent


Equipment EQUI961500032005/EU135Stripper Feed Tank is controlled by TREA4 008‐Centrifugal Collector ‐ Medium Efficiency




















Equipment EQUI962500032001/EU17914% Black Liquor Tank sends to STRU127 Stack/Vent

Equipment EQUI963472032021/EU223ClO2 Storage Tank B is controlled by TREA12 001‐Wet Scrubber ‐ High Efficiency


Equipment EQUI964EU221Dump Tank is controlled by TREA12 001‐Wet Scrubber ‐ High Efficiency


Equipment EQUI965EU222ClO2 Storage Tank A is controlled by TREA12 001‐Wet Scrubber ‐ High Efficiency


Equipment EQUI966EU248Chlorine Blowdown Tank is controlled by TREA13 001‐Wet Scrubber ‐ High Efficiency


Equipment EQUI967EU245D Filt. Tank is controlled by TREA13 001‐Wet Scrubber ‐ High Efficiency


Equipment EQUI968EU244D/C Filt. Tank is controlled by TREA13 001‐Wet Scrubber ‐ High Efficiency


Equipment EQUI969EU180#9 & #10 Brown Stock High Density Storage Tank sends to STRU128 Stack/Vent




Equipment EQUI971EU178Dirty Hot Water Tank sends to STRU126 Stack/Vent

Equipment EQUI972EU914#3 Filtrate Tank is controlled by TREA1 010‐Electrostatic Precipitator ‐ High Efficiency




Equipment EQUI973EU913#2 Filtrate Tank is controlled by TREA1 010‐Electrostatic Precipitator ‐ High Efficiency




Equipment EQUI974EU175Foam System is controlled by TREA1 010‐Electrostatic Precipitator ‐ High Efficiency







Equipment EQUI975EU912Knot Tank is controlled by TREA1 010‐Electrostatic Precipitator ‐ High Efficiency




Equipment EQUI976425032003/EU177#1 Filtrate Tank Foam Breaker is controlled by TREA1 010‐Electrostatic Precipitator ‐ High Efficiency







Equipment EQUI977EU915Blow Tank is controlled by TREA1 010‐Electrostatic Precipitator ‐ High Efficiency




Equipment EQUI978EU30562% BLS Tank is controlled by TREA1 010‐Electrostatic Precipitator ‐ High Efficiency









Equipment EQUI979EU911Turpentine Storage Tank is controlled by TREA4 008‐Centrifugal Collector ‐ Medium Efficiency













Equipment EQUI81MR906SDT scrubber flow ‐ Parametric Monitor sends to EQUI74 Data Acquisition System

Equipment EQUI82MR907ClO2 scrubber liquid supply flow rate ‐ Parametric sends to EQUI74 Data Acquisition System

Equipment EQUI83MR908Bleach Plant scrubber liquid supply flow rate ‐ Parametric sends to EQUI74 Data Acquisition System

Equipment EQUI84MR909Bleach Plant scrubber pH ‐ Parametric Monitor sends to EQUI74 Data Acquisition System

Equipment EQUI108MR341Lime Kiln H2O Pressure ‐ ParametricMonitor sends to EQUI74 Data Acquisition System

Equipment EQUI116MR905SDT scrubber pressure drop sends to EQUI74 Data Acquisition System

Equipment EQUI126MR340Lime Kiln Liquid Flow Rate ‐ Parametric Monitor sends to EQUI74 Data Acquisition System

Equipment EQUI947MR910Bleach Plant scrubber fan ‐ Parametric Monitor sends to EQUI74 Data Acquisition System

Equipment EQUI948 Boiler 2 Airflow Meter monitors EQUI16 Boiler


Equipment EQUI44EU174Brown Stock Decker ‐ Other Emission Unit sends to STRU20 Stack/Vent

Equipment EQUI52EU906UNOX A Basin ‐ Other Emission Unit is controlled by TREA32 099‐Other


Equipment EQUI53EU907UNOX B Basin ‐ Other Emission Unit is controlled by TREA32 099‐Other


Equipment EQUI49EU350Reburned Lime Bin ‐ Other Emission Unit is controlled by TREA35 018‐Fabric Filter ‐ Low Temp, T<180 Degrees F


Equipment EQUI12EU902Paint Spray Booth ‐ Spray Booth/Coating Line is controlled by TREA30 905‐Paper Filter (Not Accordian)


Equipment EQUI25EU909Off‐Machine Coater ‐ Other Emission Unit sends to STRU107 Stack/Vent

Equipment EQUI3EU173Brown Stock Washing ‐ Washer is controlled by TREA1 010‐Electrostatic Precipitator ‐ High Efficiency







Treatment TREA12CE220Wet Scrubber ‐ Cl02 Generator is monitored by EQUI82 Parametric Monitor


Treatment TREA13CE240Wet Scrubber ‐ Bleach Plant is monitored by EQUI83 Parametric Monitor

is monitored by EQUI84 Parametric Monitor



Treatment TREA15CE341Venturi Scrubber ‐ Lime Kiln is monitored by EQUI108 Parametric Monitor



Treatment TREA4CE340Centrifugal Collector ‐ Lime Kiln is controlled in series by TREA15 001‐Wet Scrubber ‐ High Efficiency

Treatment TREA10CE908Centrifugal Collector ‐ Boiler 2 is controlled in series by TREA5 010‐Electrostatic Precipitator ‐ High Efficiency

Treatment TREA2CE322Venturi Scrubber ‐ Smelt Dissolving Tank is monitored by EQUI81 Parametric Monitor



Treatment TREA3CE323Venturi Scrubber ‐ Smelt Dissolving Tank is monitored by EQUI81 Parametric Monitor



Treatment TREA16CE342Other ‐ Comb. of NCG Lime Kiln is controlled in series by TREA4 008‐Centrifugal Collector ‐ Medium Efficiency

is controlled in series by TREA15 001‐Wet Scrubber ‐ High Efficiency

Treatment TREA17CE360Other ‐ Comb. of NCG Rec. Furn is controlled in parallel by TREA2 053‐Venturi Scrubber

is controlled in parallel by TREA3 053‐Venturi Scrubber

is controlled in series by TREA1 010‐Electrostatic Precipitator ‐ High Efficiency

Treatment TREA19CE432Other ‐ Comb. of NCG Blr #2 is controlled in series by TREA5 010‐Electrostatic Precipitator ‐ High Efficiency

is controlled in series by TREA10 008‐Centrifugal Collector ‐ Medium Efficiency

Treatment TREA24CE904Other ‐ Sludge Dryer is controlled in series by TREA25 053‐Venturi Scrubber

is controlled in series by TREA26 052‐Spray Tower

Subject ItemID Seq. # Requirement

TFAC 5(07100002)

1

PERMIT SHIELD: Subject to the limitations in Minn. R. 7007.1800, compliance with the conditions of this permitshall be deemed compliance with the specific provision of the applicable requirement identified in the permit asthe 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, anyperson (including the Permittee) may also use other credible evidence to establish compliance ornoncompliance with applicable requirements.

This permit shall not alter or affect the liability of the Permittee for any violation of applicable requirements priorto or at the time of permit issuance.

2

Permit Appendices: This permit contains appendices as listed in the permit Table of Contents. The Permitteeshall comply with all requirements contained in Appendices A-J (Insignificant Activities, Ambient TRS Plan, 40CFR Pt. 63, Subp. JJJJ compliance equation, Fugitive Emissions Control Plan, Air Toxics Report, UNOXAlternative Monitoring, Scrubber Pressure Drop Monitoring Parameters, Alternative MACT PM Limits, Modelingparameters, and 40 CFR pt. 63, subp. A requirements, respectively).

Modeling parameters in Appendix I are included for reference only as described elsewhere in this permit.

3 [Stage 1] The Permitte shall limit Black Liquor Solids (virgin bone dried basis) Production <= 46410 tons permonth 12-month rolling average.

6 [Stage 1] Recordkeeping: Monthly record and monthly calculation of 12-month rolling average of the black liquorsolids production, by the 15th of the following month.

7 Reporting: The Permittee shall submit a report : Due annually, by the 30th of January, of the previous 12monthly 12-month rolling average calculations of the black liquor solids (virgin bone dried basis) production.

10

Fugitive Emissions Control Plan: The Permittee has submitted a fugitive emissions control plan for review andapproval by the Commissioner. The Plan is considered an enforceable part of the permit. The plan shall identifyall fugitive emission sources, including paved and unpaved roads, primary and contingent control measures, andrecordkeeping. The Permitee shall follow the actions and recordkeeping specified in the control plan. The planmay be amended by the Permittee with the Commissioner's approval. If the Commissioner determines thePermitee is out of compliance with Minn. R. 7011.0150 or the fugitive emission control plan, then the Permitteemay be required to amend the control plan and/or to install and operate particulate matter ambient monitors.

11

Ambient TRS Plan: The Ambient TRS Plan shall describe the steps to be taken to ensure that the ambient airTRS target is not exceeded. The Ambient TRS Plan has been submitted and approved by the MPCA on10/2/2000 (permit -003 issuance date). This plan is an enforceable part of the permit and is listed in Appendix B.This is a state only requirement and is not federally enforceable or enforceable by citizens under the Act.

12 The Permittee shall continue to comply with the Ambient TRS Plan, except for those provisions related tooperation and maintenance of the TRS monitor, after the monitor has been shut off (occurred on April 6, 2015).

Minn. R. 7007.1800, (A)(2)

Minn. R. 7007.0800, subp. 2

Title I Condition: 40 CFR52.21(k)(Modeling) & Minn. R.7007.3000

Minn. R. 7007.0800, subp. 5, Title ICondition: 40 CFR 52.21(k)(Modeling)& Minn. R. 7007.3000

Minn. R. 7007.0800, subp. 6

Minn. R. 7007.0800, subp. 2, Minn.Stat. 116.07, subd. 4a

Minn. R. 7007.0800, subp. 2

TSD Requirement (Print version)

Agency Interest Name: Boise White Paper LLC - Intl FallsActivity Number: IND20140001

Subject ItemID Seq. # RequirementTFAC 5(07100002)

11

Ambient TRS Plan: The Ambient TRS Plan shall describe the steps to be taken to ensure that the ambient airTRS target is not exceeded. The Ambient TRS Plan has been submitted and approved by the MPCA on10/2/2000 (permit -003 issuance date). This plan is an enforceable part of the permit and is listed in Appendix B.This is a state only requirement and is not federally enforceable or enforceable by citizens under the Act.

12 The Permittee shall continue to comply with the Ambient TRS Plan, except for those provisions related tooperation and maintenance of the TRS monitor, after the monitor has been shut off (occurred on April 6, 2015).

14 The Permittee shall store any fuels falling under the definition of solid waste in accordance with Minn. R.7035.2855.

15

Prior to operation of a storage facility, owners and operators shall obtain a written certification from an engineerlicensed in Minnesota stating that the storage facility is designed and constructed to meet the requirements ofthis part. A copy of this certification shall be maintained on file by the owner or operator and shall be madeavailable to the Agency upon request.

18

These requirements apply if a reasonable possibility (RP) as defined in 40 CFR Section 52.21(r)(6)(vi) existsthat a proposed project, analyzed using the actual-to-projected-actual (ATPA) test (either by itself or as part ofthe hybrid test at 40 CFR Section 52.21(a)(2)(iv)(f)) and found to not be part of a major modification, may resultin a significant emissions increase (SEI). If the ATPA test is not used for the project, or if there is no RP that theproposed project could result in a SEI, these requirements do not apply to that project. The Permittee is onlysubject to the Preconstruction Documentation requirement for a project where a RP occurs only within themeaning of 40 CFR 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 thata proposed project could result in a SEI, a permit amendment, recordkeeping, or notification may still berequired by Minn. R. 7007.1150 - 7007.1500.

19

Preconstruction Documentation -- Before beginning actual construction on a project, the Permittee shalldocument the following:

1. Project description 2. Identification of any subject item (SI) whose emissions of an NSR pollutant could be affected 3. Pre-change potential emissions of any affected existing SI, and the projected post-change potentialemissions of any affected existing or new SI. 4. A description of the applicability test used to determine that the project is not a major modification for anyregulated NSR pollutant, including the baseline actual emissions, the projected actual emissions, the amount ofemissions excluded due to increases not associated with the modification and that the SI could haveaccommodated during the baseline period, an explanation of why the amounts were excluded, and any credita..

20

The Permittee shall monitor the actual emissions of any regulated NSR pollutant that could increase as a resultof the project and that were analyzed using the ATPA test, and the potential emissions of any regulated NSRpollutant that could increase as a result of the project and that were analyzed using potential emissions in thehybrid test. The Permittee shall calculate and maintain a record of the sum of the actual and potential (if thehybrid test was used in the analysis) emissions of the regulated pollutant, in tons per year on a calendar yearbasis, for a period of 5 years following resumption of regular operations after the change, or for a period of 10years following resumption of regular operations after the change if the project increases the design capacity ofor potential to emit of any unit associated with the project.

21

The Permittee must submit a report to the Agency if the annual summed (actual, plus potential if used in hybridtest) emissions differ from the preconstruction projection and exceed the baseline actual emissions by asignificant amount as listed at 40 CFR Section 52.21(b)(23). Such report shall be submitted to the Agency within60 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) foreach 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 thepreconstruction projection.

22 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 bedemonstrated upon written request by the MPCA.

Minn. R. 7007.0800, subp. 2

Minn. R. 7035.2855

Minn. R. 7035.2855, subp. 7(A)

Minn. R. 7007.0800, subp. 2, Title ICondition: 40 CFR 52.21(r)(6) andMinn. R. 7007.3000

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

Minn. R. 7007.0800, subps. 4-5, Title ICondition: 40 CFR 52.21(r)(6) andMinn. R. 7007.3000

Minn. R. 7007.0800, subps. 4-5, Title ICondition: 40 CFR 52.21(r)(6) andMinn. R. 7007.3000




21

The Permittee must submit a report to the Agency if the annual summed (actual, plus potential if used in hybridtest) emissions differ from the preconstruction projection and exceed the baseline actual emissions by asignificant amount as listed at 40 CFR Section 52.21(b)(23). Such report shall be submitted to the Agency within60 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) foreach 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 thepreconstruction projection.

22The 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 bedemonstrated upon written request by the MPCA.

23Circumvention: Do not install or use a device or means that conceals or dilutes emissions, which wouldotherwise violate a federal or state air pollution control rule, without reducing the total amount of pollutantemitted.

24 Air Pollution Control Equipment: Operate all pollution control equipment whenever the corresponding processequipment and emission units are operated.

25

Operation and Maintenance Plan: Retain at the stationary source an operation and maintenance plan for all airpollution control equipment. At a minimum, the O & M plan shall identify all air pollution control equipment andcontrol practices and shall include a preventative maintenance program for the equipment and practices, adescription of (the minimum but not necessarily the only) corrective actions to be taken to restore the equipmentand practices to proper operation to meet applicable permit conditions, a description of the employee trainingprogram for proper operation and maintenance of the control equipment and practices, and the records kept todemonstrate plan implementation.

26

Operation Changes: In any shutdown, breakdown, or deviation the Permittee shall immediately take all practicalsteps to modify operations to reduce the emission of any regulated air pollutant. The Commissioner may requirefeasible and practical modifications in the operation to reduce emissions of air pollutants. No emissions unitsthat have an unreasonable shutdown or breakdown frequency of process or control equipment shall bepermitted to operate.

27Fugitive Emissions: Do not cause or permit the handling, use, transporting, or storage of any material in amanner which may allow avoidable amounts of particulate matter to become airborne. Comply with all otherrequirements listed in Minn. R. 7011.0150.

28Noise: The Permittee shall comply with the noise standards set forth in Minn. R. 7030.0010 to 7030.0080 at alltimes during the operation of any emission units. This is a state only requirement and is not enforceable by theEPA Administrator or citizens under the Clean Air Act.

29 Inspections: The Permittee shall comply with the inspection procedures and requirements as found in Minn. R.7007.0800, subp. 9(A).

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

Minn. R. 7011.0020

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

Minn. R. 7007.0800, subp. 14, Minn. R.7007.800, subp. 16(J)

Minn. R. 7019.1000, subp. 4

Minn. R. 7011.0150

Minn. R. 7030.0010-7030.0080




28

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

29 Inspections: The Permittee shall comply with the inspection procedures and requirements as found in Minn. R.7007.0800, subp. 9(A).

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

31 Performance Testing: Conduct all performance tests in accordance with Minn. R. ch. 7017 unless otherwisenoted in this permit.

32

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: due30 days before each Performance TestPerformance Test Pre-test Meeting: due 7 days before each Performance TestPerformance Test Report: due 45 days after each Performance Test

The Notification, Test Plan, and Test Report must be submitted in a format specified by the commissioner.

33

Limits set as a result of a performance test (conducted before or after permit issuance) apply until supersededas stated in the MPCA's Notice of Compliance letter granting preliminary approval. Preliminary approval is basedon 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.

34

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, andany corrective action that resulted. The Permittee shall include the calibration frequencies, procedures, andmanufacturer's specifications (if applicable) in the Operations and Maintenance Plan. Any requirements applyingto continuous emission monitors are listed separately in this permit.

35

Operation of Monitoring Equipment: Unless noted elsewhere in this permit, monitoring a process or controlequipment connected to that process is not necessary during periods when the process is shutdown, or duringchecks of the monitoring systems, such as calibration checks and zero and span adjustments. If monitoringrecords are required, they should reflect any such periods of process shutdown or checks of the monitoringsystem.

36 Recordkeeping: Retain all records at the stationary source, unless otherwise specified within this permit, for aperiod of five (5) years from the date of monitoring, sample, measurement, or report. Records which must beretained at this location include all calibration and maintenance records, all original recordings for continuousmonitoring instrumentation, and copies of all reports required by the permit. Records must conform to therequirements listed in Minn. R. 7007.0800, subp. 5(A).

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

Minn. R. 7007.0800, subp. 16

Minn. R. ch. 7017

Minn. R. 7017.2018, Minn. R.7017.2030, subps. 1-4, Minn. R.7017.2035, subps. 1-2

Minn. R. 7017.2025, subp. 3

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

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




35

Operation of Monitoring Equipment: Unless noted elsewhere in this permit, monitoring a process or controlequipment connected to that process is not necessary during periods when the process is shutdown, or duringchecks of the monitoring systems, such as calibration checks and zero and span adjustments. If monitoringrecords are required, they should reflect any such periods of process shutdown or checks of the monitoringsystem.

36

Recordkeeping: Retain all records at the stationary source, unless otherwise specified within this permit, for aperiod of five (5) years from the date of monitoring, sample, measurement, or report. Records which must beretained at this location include all calibration and maintenance records, all original recordings for continuousmonitoring instrumentation, and copies of all reports required by the permit. Records must conform to therequirements listed in Minn. R. 7007.0800, subp. 5(A).

37Recordkeeping: 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 recordsof the emissions resulting from those changes.

38

If the Permittee determines that no permit amendment or notification is required prior to making a change, thePermittee must retain records of all calculations required under Minn. R. 7007.1200. These records shall be keptfor 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 atthe stationary source or office of the stationary source for all other years. The records may be maintained ineither electronic or paper format.

39

Shutdown Notifications: Notify the Commissioner at least 24 hours in advance of a planned shutdown of anycontrol equipment or process equipment if the shutdown would cause any increase in the emissions of anyregulated air pollutant. If the owner or operator does not have advance knowledge of the shutdown, notificationshall be made to the Commissioner as soon as possible after the shutdown. However, notification is not requiredin 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 shutdownand the estimated duration. The owner or operator shall notify the Commissioner when the shutdown is over.

40

Breakdown Notifications: Notify the Commissioner within 24 hours of a breakdown of more than one hourduration of any control equipment or process equipment if the breakdown causes any increase in the emissionsof any regulated air pollutant. The 24-hour time period starts when the breakdown was discovered or reasonablyshould have been discovered by the owner or operator. However, notification is not required in thecircumstances 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 Commissionerof the cause of the breakdown and the estimated duration. The owner or operator shall notify the Commissionerwhen the breakdown is over.

41Notification 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 permitconditions which could endanger human health or the environment.

42

Notification of Deviations Endangering Human Health or the Environment Report: Within 2 working days ofdiscovery, notify the Commissioner in writing of any deviation from permit conditions which could endangerhuman 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.

43 Parameters Used in Modeling (non-criteria pollutants):If the Permittee proposes to emit any pollutant in addition to those listed in the Boise Cascade Air ToxicsReview, dated January 1999 (summarized in Appendix E), or proposes to increase the emission rate of anypollutant, the Permittee shall first use the Air Toxics Review (ATR) as a template for re-evaluating the risk due tothe change in emissions. If the proposed change may adversely affect the calculated risk, e.g. the change is anincrease in one of the pollutants determined to be a risk driver, (i.e. a pollutant contributing to 95% of the acute,subchronic, or chronic hazard index or 95% of the excess cancer risk), then the Permittee shall submit a reportto the MPCA of the proposed change and demonstrate that the recalculated risk for all pollutants emitted fromthe facility does not exceed the acceptable risk criteria used in the ATR. The Permittee shall receive writtenapproval from the MPCA before making any changes...

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

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

Minn. R. 7007.1200, subp. 4

Minn. R. 7019.1000, subp. 3

Minn. R. 7019.1000, subp. 2

Minn. R. 7019.1000, subp. 1

Minn. R. 7019.1000, subp. 1




42

Notification of Deviations Endangering Human Health or the Environment Report: Within 2 working days ofdiscovery, notify the Commissioner in writing of any deviation from permit conditions which could endangerhuman 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.

43

Parameters Used in Modeling (non-criteria pollutants):If the Permittee proposes to emit any pollutant in addition to those listed in the Boise Cascade Air ToxicsReview, dated January 1999 (summarized in Appendix E), or proposes to increase the emission rate of anypollutant, the Permittee shall first use the Air Toxics Review (ATR) as a template for re-evaluating the risk due tothe change in emissions. If the proposed change may adversely affect the calculated risk, e.g. the change is anincrease in one of the pollutants determined to be a risk driver, (i.e. a pollutant contributing to 95% of the acute,subchronic, or chronic hazard index or 95% of the excess cancer risk), then the Permittee shall submit a reportto the MPCA of the proposed change and demonstrate that the recalculated risk for all pollutants emitted fromthe facility does not exceed the acceptable risk criteria used in the ATR. The Permittee shall receive writtenapproval from the MPCA before making any changes...

44

Modeled Parameters for NOx and SO2: The parameters used in NOx modeling for permit number07100002-001 and SO2 modeling for permit number 07100002-011 are listed in Appendix I of this permit. Theparameters describe the operation of the facility at maximum permitted capacity. The purpose of listing theparameters in the appendix is to provide a benchmark for future changes.

46

PM < 10 micron : The Permittee shall submit a computer dispersion modeling protocol : Due 1461 calendar daysafter Permit Issuance Date. This protocol will describe the proposed modeling methodology and input data, inaccordance with MPCA modeling guidance for Title V air dispersion modeling analyses. The protocol will bebased on projected operating conditions under the next permit term.

47 PM < 10 micron : The Permittee shall submit computer dispersion modeling results : Due 1826 calendar daysafter Permit Issuance Date.

50

Application for Permit Amendment: If a permit amendment is needed, submit an application in accordance withthe requirements of Minn. R. 7007.1150 through Minn. R. 7007.1500. Submittal dates vary, depending on thetype of amendment needed.

Upon adoption of a new or amended federal applicable requirement, and if there are more than 3 yearsremaining in the permit term, the Permittee shall file an application for an amendment within nine months ofpromulgation of the applicable requirement, pursuant to Minn. R. 7007.0400, subp. 3.

51

Extension Requests: The Permittee may apply for an Administrative Amendment to extend a deadline in apermit 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 40CFR pt. 63 are examples of deadlines for which the MPCA does not have authority to grant extensions andtherefore do not meet the requirements of Minn. R. 7007.1400, subp. 1(H).

52 The Permittee shall submit an application for permit reissuance : Due 180 calendar days before PermitExpiration Date.

53 The Permittee shall submit a semiannual deviations report : Due semiannually, by the 30th of January and JulyThe first semiannual report submitted by the Permittee shall cover the calendar half-year in which the permit isissued. The first report of each calendar year covers January 1 - June 30. The second report of each calendaryear covers July 1 - December 31. If no deviations have occurred, the Permittee shall submit the report statingno deviations.

Minn. R. 7007.0800, subp. 2

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, Title I Condition: 40 CFR52.21(k)(modeling) & Minn. R.7007.3000

Minn. R. 7007.0100, Minn. R.7007.0800, subp. 2, Minn. R.7009.0020, Minn. Stat. 116.07, subd.4a, Minn. Stat. 116.07, subd. 9

Minn. R. 7007.0100, Minn. R.7007.0800, subp. 2, Minn. R.7009.0020, Minn. Stat. 116.07, subd.4a, Minn. Stat. 116.07, subd. 9

Minn. R. 7007.0400, subp. 3, Minn. R.7007.1150 - 7007.1500

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

Minn. R. 7007.0400, subp. 2




52The Permittee shall submit an application for permit reissuance : Due 180 calendar days before PermitExpiration Date.

53

The Permittee shall submit a semiannual deviations report : Due semiannually, by the 30th of January and JulyThe first semiannual report submitted by the Permittee shall cover the calendar half-year in which the permit isissued. The first report of each calendar year covers January 1 - June 30. The second report of each calendaryear covers July 1 - December 31. If no deviations have occurred, the Permittee shall submit the report statingno deviations.

55The Permittee shall submit a compliance certification : Due annually, by the 31st of January (for the previouscalendar 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.

56 Emission Inventory Report: due on or before April 1 of each calendar year following permit issuance, to besubmitted on a form approved by the Commissioner.

57 Emission Fees: due 30 days after receipt of an MPCA bill.

58

EER: The Permittee shall submit excess emission/downtime report : Due by 30 days after the end of eachcalendar quarter following permit issuance Submit Deviations Reporting Form DRF-1 as amended. The EERshall indicate all periods of monitor bypass and all periods of exceedances of the limit including exceedancesallowed by an applicable standard, i.e. during startup, shutdown, and malfunctions. The EER must be submittedeven if there were no excess emissions, downtime or bypasses during the quarter.

COMG 5(GP420)

1 The Permittee shall limit emission of Nitrogen Oxides <= 3.67 tons per day from combustion sources (EQUI 9,EQUI 15, EQUI 16, EQUI 17, and EQUI 18).

2

Calculate: Calculate and record NOx emissions daily from combustion sources. The NOx emissions from EQUI9, EQUI 15, EQUI 16, EQUI 17, and EQUI 18 shall be summed together and compared to the NOx limit for thecombustion sources (3.67 tons/day). The NOx emissions from each subject item are to be determined from theNOx CEMS for that subject item. Any exceedances shall be reported on a semi-annual basis with the CEMSEERs.

(Calculations associated with Title I Condition).

3 The Permittee shall limit emissions of Nitrogen Oxides <= 4.18 tons per day. This limit is the total NOx cap forthe combustion sources (Boilers #1, #2, #3, #9, and the recovery furnace) (EQUI 15, EQUI 16, EQUI 17, EQUI18, EQUI 9, respectively) as well as the lime kiln and smelt dissolving tank (EQUI 13 and EQUI 945).

Minn. R. 7007.0800, subp. 6(A)(2)

Minn. R. 7007.0800, subp. 6(C)

Minn. R. 7019.3000-7019.3100

Minn. R. 7002.0005-7002.0095

40 CFR 60.7(c), Minn. R. 7007.1075,Minn. R. 7017.1110, subps. 1-2

Title I Condition: 40 CFR52.21(o)(visibility) & Minn. R.7007.3000




Subject ItemID Seq. # RequirementCOMG 5(GP420)

2

Calculate: Calculate and record NOx emissions daily from combustion sources. The NOx emissions from EQUI9, EQUI 15, EQUI 16, EQUI 17, and EQUI 18 shall be summed together and compared to the NOx limit for thecombustion sources (3.67 tons/day). The NOx emissions from each subject item are to be determined from theNOx CEMS for that subject item. Any exceedances shall be reported on a semi-annual basis with the CEMSEERs.


3The Permittee shall limit emissions of Nitrogen Oxides <= 4.18 tons per day. This limit is the total NOx cap forthe combustion sources (Boilers #1, #2, #3, #9, and the recovery furnace) (EQUI 15, EQUI 16, EQUI 17, EQUI18, EQUI 9, respectively) as well as the lime kiln and smelt dissolving tank (EQUI 13 and EQUI 945).

4

Calculate: Calculate and record NOx emissions daily from the smelt dissolving tank (EQUI 945) and the lime kiln(EQUI 13). The NOx emissions shall be calculated by multiplying the emission factor determined from the mostrecent MPCA approved performance test and the applicable production rate. These NOx emissions shall beadded to the emissions determined from the NOx CEMS on a daily basis and shall then be compared to the totalNOx emission limit for COMG 5. Any exceedances shall be reported on a semi-annual basis with the CEMSEERs.


3170

Nitrogen Oxides: Protocol for Re-Setting the Emission Factor Used For Calculating Emissions: The Permitteeshall conduct performance testing under conditions that produce the maximum emission rate, using US EPAreference method 7E to measure the emission factor as required elsewhere in this permit. The Permittee shallreport the test result in lbs/hr for EQUI 13 and lbs/ton of BLS for EQUI 945 in the performance test reportrequired by Minn. R. 7017.2035, subp. 1.

The emission factor used for calculating emissions shall be re-set to the 3-hour average emission rate in lbs/hrfor EQUI 13, and shall be re-set to the emission rate in lbs/ton of BLS for EQUI 945, measured during the mostrecent MPCA-approved emission factor performance test.

The new emission factor used for calculating emissions determined using this Protocol shall be effective upon ..

COMG 6(GP340)

2 HAP Control: Gases from the LVHC (low volume, high concentration) system (COMG 6) shall be combusted inthe lime kiln (TREA 16), or Boilers #2 or #1 (TREA 19 and TREA 18) as backup.

3 Enclosures and Venting: All equipment listed in this COMG shall be enclosed and vented into a closed-ventsystem meeting the requirements specified in 40 CFR Section 63.450 and as described below.

5

NCG (non-condensable gas) (LVHC) Venting: The Permittee shall control NCG (LVHC) through thermaloxidation in either the Lime Kiln (primary device), Power Boiler #2 (secondary device) or Power Boiler #1(tertiary device). When none of these control devices is available, the Permittee may vent NCG (LVHC) directlyto atmosphere. Upon venting NCG (LVHC) in an uncontrolled manner, the Permittee shall initiate investigation ofthe cause and take necessary action to re-establish control. If control cannot be re-established within 30minutes, the Permittee shall initiate shutdown of the NCG (LVHC)-emitting sources in a controlled manner. TheNCG (LVHC)-emitting sources, except for the evaporators, shall be shut down within 30 minutes and theremaining sources (the evaporators) shall be shutdown within two hours. The Permittee shall not re-start any ofthe NCG (LVHC) emitting sources until one of the control systems is operational.

6

TRS Control: Gases from the NCG (LVHC) sources (batch digester system (blow heat recovery), reliefcondensers and decant system, foul condensate stripper feed tank, and the multiple-effect evaporator) shall becombusted in the lime kiln which shall be equipped with a scrubber. The TRS limit from the lime kiln shall be 8ppmvd corrected to 10% oxygen.

9 Hours <= 30 hours per year 12-month rolling sum to be calculated by the 15th of each month of NCG (LVHC)Venting (venting directly to the atmosphere, rather than being oxidized in the lime kiln or Boilers #1 or #2).



Minn. R. 7017.2025, Title I Condition:40 CFR 52.21(o)(visibility) & Minn. R.7007.3000

40 CFR 63.443(a)(1)(i), 40 CFR63.443(d)(4)

40 CFR 63.443(c), Minn. R. 7011.7700

Minn. R. 7007.0800, subp. 2

40 CFR 60.283(a)(1)(i), Minn. R.7011.2450




6

TRS Control: Gases from the NCG (LVHC) sources (batch digester system (blow heat recovery), reliefcondensers and decant system, foul condensate stripper feed tank, and the multiple-effect evaporator) shall becombusted in the lime kiln which shall be equipped with a scrubber. The TRS limit from the lime kiln shall be 8ppmvd corrected to 10% oxygen.

9 Hours <= 30 hours per year 12-month rolling sum to be calculated by the 15th of each month of NCG (LVHC)Venting (venting directly to the atmosphere, rather than being oxidized in the lime kiln or Boilers #1 or #2).

10

Sulfur Dioxide <= 115 tons per year 12-month rolling sum, Boilers #1 and #2 shall be combined, on a 12-monthrolling sum basis. TRS Control - Backup and Emergency: During shutdowns and malfunctions of the lime kiln, non-condensablegases from the NCG (LVHC) sources (batch digester system, relief condensers and decant system, foulcondensate stripper feed tank, and the multiple-effect evaporator system) shall be routed to Boiler #2 (TREA 19)for oxidation. During emergency situations when neither the lime kiln (TREA 16) or Boiler #2 (TREA 19) areavailable, the NCG shall be oxidized in Boiler #1 (TREA 18). NCG oxidation in Boilers #1 and #2, in aggregate,shall be limited to allow emissions of SO2 to no more than 115 tons per year from Boilers #1 and #2 together.

12Report: The Permittee shall submit a report : Due annually, by the 30th of January starting 10/13/2010, a reportof the previous 12 monthly 12-month rolling sum calculations of NCG (LVHC) oxidized in Boiler #1 and #2 and ofNCG (LVHC) venting.

3840

Daily Recordkeeping. On each day of operation, the Permittee shall calculate, record, and maintain a record ofthe total hours of: a) hours during which NCG (LVHC) are oxidized in Boiler #1 or #2 b) NCG venting hours.

3850

Monthly Recordkeeping.By the 15th of the month, the Permittee shall calculate and record the following:1) The total NCG venting hours for the previous calendar month using the daily records; and2) The 12-month rolling sum of NCG venting hours for the previous 12-month period by summing the monthlyhours of venting for the previous 12 months; and

1) the calculation of SO2 emissions from Boiler #1 and #2 for the previous month; and2) The 12-month rolling sum of SO2 emissions from Boiler #1 and #2 for the previous 12-month period. (Boiler#1 SO2 emissions shall be calculated using emission factors and operating data, including hours of NCG(LVHC) oxidation. Boiler #2 SO2 emissions shall be calculated using SO2 CEMS data and boiler operating data,including hours of NCG (LVHC) oxidation).

COMG 7(GP421)

1

COMG 7 includes EQUIs 31, 34, 37, 961, STRUs 108 and 109, and TREA 38.The pulping process condensates from the following equipment systems shall be treated to meet therequirements below:- Each digester system;- Each turpentine recovery system;- Each evaporator system condensate from:(i) The vapors from each stage where weak liquor is introduced (feed stages); and(ii) Each evaporator vacuum system for each stage where weak liquor is introduced (feed stages)- Each HVLC collection system; and- Each LVHC collection system...

2 The Permittee shall collect HAPs - Total >= 11.1 pounds per ton of ODP (oven-dried pulp) that are contained inthe pulping process condensates from the equipment described above.

3 Condensate Treatment - HAPs: Regulated condensates shall be hardpiped to the UNOX closed biologicaltreatment system. The UNOX treatment system shall be operated in a manner that treats the collectedcondensate according to the following methods:

- Discharge the pulping process condensate below the liquid surface of the UNOX biological treatment systemand treat the pulping process condensates, and

- Treat to reduce or destroy the total HAPs by 92% or more by weight, or at least 10.2 pounds of total HAP perton of ODP.

Minn. R. 7007.0800, subps. 4-5, Title ICondition: 40 CFR pt. 52, 21(j)(BACT)& Minn. R. 7007.3000

Title I Condition: 40 CFR 52.21(j)(BACT) & Minn. R. 7007.3000

Minn. R. 7007.0800, subp. 6

Minn. R. 7007.0800, subp. 5, Title ICondition: 40 CFR 52.21(j)(BACT) andMinn. R. 7007.3000

Minn. R. 7007.0800, subps. 4-5

40 CFR 63.446(c), Minn. R. 7011.7700

40 CFR 63.446(c)(3), Minn. R.7011.7700




2The Permittee shall collect HAPs - Total >= 11.1 pounds per ton of ODP (oven-dried pulp) that are contained inthe pulping process condensates from the equipment described above.

3

Condensate Treatment - HAPs: Regulated condensates shall be hardpiped to the UNOX closed biologicaltreatment system. The UNOX treatment system shall be operated in a manner that treats the collectedcondensate according to the following methods:

- Discharge the pulping process condensate below the liquid surface of the UNOX biological treatment systemand treat the pulping process condensates, and

- Treat to reduce or destroy the total HAPs by 92% or more by weight, or at least 10.2 pounds of total HAP perton of ODP.

4Condensate Closed Collection System: Regulated condensates shall be collected and conveyed in a closedcollection system that is designed and operated to meet the requirements of 40 CFR Section 63.446(c) and 40CFR Section 63.962(a)(2).

5

Condensate Monitoring Requirements: The Permittee shall use the average MLVSS measured during the mostrecent performance test of the UNOX system, that demonstrates compliance, as the minimum MLVSSdemonstrating continuous compliance during subsequent operation. The Permittee shall operate the UNOXsystem in a manner consistent with the minimum MLVSS. EPA letter dated August 14, 2002, approvedalternative monitoring. See Appendix F.

6Daily Recordkeeping. On each day of operation, the Permittee shall, using methods outlined in Appendix C to 40CFR pt. 63, calculate, record, and maintain a record of the mixed liquor volatile suspended solids (MLVSS)concentration, in grams/Liter, in the UNOX system.

7

Reporting: Operation of the UNOX system below the minimum MLVSS shall constitute a violation of emissionsstandards in 40 CFR pt. 63, subp. S and shall be reported as a period of excess emissions. Report any/allexcess emissions quarterly within 30 days following the end of the calendar quarter. The report must contain therequired elements specified in 40 CFR Section 63.10(c).

8

HAPs - Total (measured as Methanol) : The Permittee shall conduct a performance test : Due before 12/31/2018every 60 months to show 92% (or 10.2 pounds per ton of ODP) destruction of HAPs and to establish theminimum MLVSS that will be used to show continuous compliance, using methods outlined in 40 CFR Part 63,Appendix C. The first test is due by the date specified and all subsequent tests are due by the end of each 60-month periodfollowing that date. Testing conducted during the 60 days prior to the performance test due date satisfies the performance test duedate, 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 ..

COMG 8(GP423)

1Hopper flush tank (EQUI 950), rapid drain tank (EQUI 951), precipitator salt-cake mix tank (EQUI 956), 55%BLS tank (EQUI 957), HL swing tank (EQUI 958), 72% BLS tank (EQUI 959), and 62% BLS tank (EQUI 978)shall be controlled with COMG 8 through gas combustion, but are not subject to Section 63, Subpart S.

2 Periods of excess emissions reported under 40 CFR Section 63.455 shall not be a violation of 40 CFR Section63.443 (c) and (d) provided that the time of excess emissions (excluding periods of startup, shutdown, ormalfunction) divided by the total process operating time in a semi-annual reporting period does not exceed fourpercent for control devices used to reduce the total HAP emissions from the HVLC system.

40 CFR 63.446(e)(2),(3),&(5), Minn. R.7011.7700

40 CFR 63.446, 40 CFR 63.962(a)(2),Minn. R. 7011.7700

40 CFR 63.453, Minn. R. 7007.0800,subp. 4, Minn. R. 7011.7700

Minn. R. 7007.0800, subp. 5

40 CFR 63.455, Minn. R. 7007.0800,subp. 6, Minn. R. 7011.7700

Minn. R. 7017.2020, subp. 1

Minn. R. 7007.0800, subp. 2




1

Hopper flush tank (EQUI 950), rapid drain tank (EQUI 951), precipitator salt-cake mix tank (EQUI 956), 55%BLS tank (EQUI 957), HL swing tank (EQUI 958), 72% BLS tank (EQUI 959), and 62% BLS tank (EQUI 978)shall be controlled with COMG 8 through gas combustion, but are not subject to Section 63, Subpart S.

2

Periods of excess emissions reported under 40 CFR Section 63.455 shall not be a violation of 40 CFR Section63.443 (c) and (d) provided that the time of excess emissions (excluding periods of startup, shutdown, ormalfunction) divided by the total process operating time in a semi-annual reporting period does not exceed fourpercent for control devices used to reduce the total HAP emissions from the HVLC system.

3 Enclosures and Venting: All equipment subject to 40 CFR pt. 63, subp. S listed in this COMG shall be enclosedand vented into a closed-vent system meeting the requirements specified in 40 CFR Section 63.450.

4 COMG 8 gases shall be combusted in the Recovery Furnace (TREA 17), which is subject to 40 CFR Section60.283(a)(2).

COMG 11(GP429)

3The Permittee shall limit emissions of Chlorine <= 0.17 pounds per hour 3-hour average, as determined byperformance test. (Limit established due to risk assessment performed as part of PSD permitting for 1989permit, number 102A-89-OT-2).

6The Permittee shall limit emissions of Chlorine Dioxide <= 2.2 pounds per hour 3-hour average, as determinedby performance test. (Limit established due to risk assessment performed as part of PSD permitting for 1989permit, number 102A-89-OT-2).

7The Permittee shall vent emissions from COMG 11 to TREA 12 whenever COMG 11 operates, and operate andmaintain TREA 12 at all times that any emissions are vented to TREA 12. The Permittee shall document periodsof non-operation of the control equipment. Additional requirements are listed at TREA 12.

COMG 12(GP430)

2

The Permittee shall limit emissions of HAPs - Total <= 10 parts per million or less than or equal to 0.02 lb per tonof oven-dried pulp or reduce the Total Chlorinated HAP mass entering the control device by 99% or more byweight. Here, Total HAPs refers to Total Chlorinated HAPs (not including chloroform) based on the sum of allindividual chlorinated HAPs or as chlorine.

3 The Permittee shall limit emissions of Chlorine <= 0.41 pounds per hour 3-hour average, as determined byperformance test.

40 CFR 63.443, Minn. R. 7011.7700

40 CFR 63.443(c), Minn. R. 7011.7700

40 CFR 60.283(a), Minn. R. 7011.7700

Minn. R. 7007.0800, subp. 2

Minn. R. 7007.0800, subp. 2

Minn. R. 7007.0800, subp. 14, Minn. R.7007.0800, subp. 2

40 CFR 63.445(c), Minn. R. 7011.7700




2

The Permittee shall limit emissions of HAPs - Total <= 10 parts per million or less than or equal to 0.02 lb per tonof oven-dried pulp or reduce the Total Chlorinated HAP mass entering the control device by 99% or more byweight. Here, Total HAPs refers to Total Chlorinated HAPs (not including chloroform) based on the sum of allindividual chlorinated HAPs or as chlorine.

3 The Permittee shall limit emissions of Chlorine <= 0.41 pounds per hour 3-hour average, as determined byperformance test.

4 The Permittee shall limit emissions of Chlorine Dioxide <= 1.2 pounds per hour 3-hour average, as determinedby performance test.

6

The Permittee shall comply with paragraph (d)(1) or (d)(2) of 40 CFR Section 63.445 (summarized below) toreduce chloroform air emissions to the atmosphere. The Permittee shall comply with the following: (1) Comply with the applicable effluent limitation guidelines and standards specified in 40 CFR pt. 430; (2) Use no hypochlorite or chlorine for bleaching in the bleaching system or line.

7Enclosures and Venting: Equipment listed at STRU 75, and which are associated with equipment wherebleaching chemicals are added, shall be enclosed and vented into a closed-vent system meeting therequirements specified in 40 CFR Section 63.450.

12

Control Equipment Operation: (Additional requirements listed at TREA 13) The Permittee shall operate the gasscrubber (TREA 13) in a manner consistent with the minimum or maximum (as appropriate) operating parametervalue or procedure required to be monitored under 40 CFR Section 63.453(a) through (n), as established byperformance test, and as described in 40 CFR Section 63.453(o). Operation of the control device belowminimum operating parameter values or above maximum operating parameter values established under 40 CFRpt. 63, subp. S shall constitute a violation of the applicable emission standard of 40 CFR pt. 63, subp. S andshall be reported as a period of excess emissions.

20230

HAPs - Total : The Permittee shall conduct a performance test : Due before 07/22/2020 every 60 months tomeasure emissions. The first test is due by the date specified and all subsequent tests are due by the end ofeach 60-month period following that date. The performance test shall be conducted at worst case conditions asdefined at Minn. R. 7017.2025, subp. 2, using EPA Reference Method 26A, or other method approved by MPCAin the performance test plan approval.

Testing conducted during the 60 days prior to the performance test due date satisfies the performance test duedate, 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; or3) within a Notice of Compliance letter. Testing conducted more than two months prior to the performance test ..

COMG 13(GP431)

1

Subject Items subject to 40 CFR pt. 63, subp. DDDDD: Boiler #1 (EQUI 15), Boiler #2 (EQUI 16), Boiler #3(EQUI 17), and Boiler #9 (EQUI 18). All submittals and notifications under 40 CFR pt. 63, subp. DDDDD shall be sent to both the MPCA and EPAcontacts listed on Page 4 of this permit, unless otherwise noted.

17 The MPCA does not have delegation for this standard, but MPCA must be copied on all submittals/notifications.

Minn. R. 7007.0800, subp. 2

Minn. R. 7007.0800, subp. 2

40 CFR 63.445(d), Minn. R. 7011.7700

40 CFR 63.443(c), Minn. R. 7011.7700

40 CFR 63.453(o), Minn. R. 7011.7700

40 CFR 63.457(a)(2), Minn. R.7011.7700

Minn. R. 7007.0800, subp. 2




1

Subject Items subject to 40 CFR pt. 63, subp. DDDDD: Boiler #1 (EQUI 15), Boiler #2 (EQUI 16), Boiler #3(EQUI 17), and Boiler #9 (EQUI 18). All submittals and notifications under 40 CFR pt. 63, subp. DDDDD shall be sent to both the MPCA and EPAcontacts listed on Page 4 of this permit, unless otherwise noted.

17 The MPCA does not have delegation for this standard, but MPCA must be copied on all submittals/notifications.

18 The Permittee must conduct a tune-up of the boiler or process heater annually as specified in 40 CFR Section63.7540(a)(10) beginning January 31, 2016.

19Each annual tune-up specified in 40 CFR Section 63.7540(a)(10) must be no more than 13 months after theprevious tune-up. This frequency does not apply to units with continuous oxygen trim systems that maintain anoptimum air to fuel ratio.

30

The Permittee must conduct an annual tune-up of the boiler or process heater to demonstrate continuouscompliance as specified below:

1. As applicable, inspect the burner, and clean or replace any components of the burner as necessary (thePermittee may delay the burner inspection until the next scheduled unit shutdown). Units that produce electricityfor sale may delay the burner inspection until the first outage, not to exceed 36 months from the previousinspection. At units where entry into a piece of process equipment or into a storage vessel is required tocomplete the tune-up inspections, inspections are required only during planned entries into the storage vessel orprocess equipment;

2. Inspect the flame pattern, as applicable, and adjust the burner as necessary to optimize the flame pattern. T..

33 If the unit is not operating on the required date for a tune-up, the tune-up must be conducted within 30 calendardays of startup.

34

At all times, the Permittee must operate and maintain any affected source, including associated air pollutioncontrol equipment and monitoring equipment, in a manner consistent with safety and good air pollution controlpractices for minimizing emissions. Determination of whether such operation and maintenance procedures arebeing used will be based on information available to the Administrator that may include, but is not limited to,monitoring results, review of operation and maintenance procedures, review of operation and maintenancerecords, and inspection of the source.

38

Assertion of Affirmative Defense:To establish the affirmative defense in any action to enforce such a standard, The Permittee must timely meetthe reporting requirements in 40 CFR Section 63.7501(b), and must prove by a preponderance of evidence theitems described in 40 CFR Section 63.7501(a).

39 The Permittee seeking to assert an affirmative defense shall submit a written report to the Administrator with allnecessary supporting documentation, that it has met the requirements set forth in 40 CFR Section 63.7500. Thisaffirmative defense report shall be included in the first periodic compliance, deviation report or excess emissionreport otherwise required after the initial occurrence of the violation of the relevant standard (which may be theend of any applicable averaging period). If such compliance, deviation report or excess emission report is dueless than 45 days after the initial occurrence of the violation, the affirmative defense report may be included inthe second compliance, deviation report or excess emission report due after the initial occurrence of the violationof the relevant standard.

Minn. R. 7007.0800, subp. 2

40 CFR 63.7500(a)(1), Table 3

40 CFR 63.7515(d), 40 CFR63.7540(a)(10)

40 CFR 63.7540(a)(10)

40 CFR 63.7515(g), 40 CFR63.7540(a)(13)

40 CFR 63.7500(a)(3)

40 CFR 63.7501(a)




38

Assertion of Affirmative Defense:To establish the affirmative defense in any action to enforce such a standard, The Permittee must timely meetthe reporting requirements in 40 CFR Section 63.7501(b), and must prove by a preponderance of evidence theitems described in 40 CFR Section 63.7501(a).

39

The Permittee seeking to assert an affirmative defense shall submit a written report to the Administrator with allnecessary supporting documentation, that it has met the requirements set forth in 40 CFR Section 63.7500. Thisaffirmative defense report shall be included in the first periodic compliance, deviation report or excess emissionreport otherwise required after the initial occurrence of the violation of the relevant standard (which may be theend of any applicable averaging period). If such compliance, deviation report or excess emission report is dueless than 45 days after the initial occurrence of the violation, the affirmative defense report may be included inthe second compliance, deviation report or excess emission report due after the initial occurrence of the violationof the relevant standard.

40

Compliance Report: submit a compliance status report : Due annually, by the 31st of January The Permitteeshall submit an annual compliance report starting 1/31/2016.Each subsequent compliance report must cover the applicable 1-year period from January 1 to December 31.Annual compliance reports must be postmarked or submitted no later than January 31.

42

A Compliance Report must contain the following:

1. Information required in 40 CFR Section 63.7550(c)(1) through (5);

2. If there were no deviations from the requirements for work practice standards in Table 3 of 40 CFR pt. 63,subp. DDDDD that apply, a statement that there were no deviations from the work practice standards during thereporting period; and

3. If there was a deviation from a work practice standard during the reporting period, the report must contain theinformation in 40 CFR Section 63.7550(d).

43

A compliance report must contain the following information:

1. Company and Facility name and address.

2. Process unit information, emissions limitations, and operating parameter limitations.

3. Date of report and beginning and ending dates of the reporting period.

4. The total operating time during the reporting period.

5. Include the date of the most recent tune-up for each unit subject to only the requirement to conduct a biennia..

51

For each deviation from an emission limit or operating limit in 40 CFR pt. 63, subp. DDDDD that occurs at anindividual boiler or process heater where a CMS is not used to comply with that emission limit or operating limit,the compliance report must additionally contain the following information:

1. A description of the deviation and which emission limit or operating limit from which there was a deviation.

2. Information on the number, duration, and cause of deviations (including unknown cause), as applicable, andthe corrective action taken.

3. If the deviation occurred during an annual performance test, provide the date the annual performance testwas completed.

52 Records to Keep. The Permittee must keep records of the occurrence and duration of each malfunction of theboiler or of the associated air pollution control and monitoring equipment.

53

Records to Keep. The Permittee must keep records of actions taken during periods of malfunction to minimizeemissions in accordance with the general duty to minimize emissions in 40 CFR Section 63.7500(a)(3), includingcorrective actions to restore the malfunctioning boiler, air pollution control, or monitoring equipment to its normalor usual manner of operation.

54 If a malfunction occurred during the reporting period, the report must include the number, duration, and a briefdescription for each type of malfunction which occurred during the reporting period and which caused or mayhave caused any applicable emission limitation to be exceeded. The report must also include a description ofactions taken by the Permittee during a malfunction of a boiler, process heater, or associated air pollution controldevice or CMS to minimize emissions in accordance with Section 63.7500(a)(3), including actions taken tocorrect the malfunction.

40 CFR 63.7501(b)

40 CFR 63.7550(b), 40 CFR63.7550(a), Table 9

40 CFR 63.7550(b), 40 CFR63.7550(a), Table 9

40 CFR 63.7550(c)

40 CFR 63.7550(d)

40 CFR 63.7555(d)(7), Minn. R.7011.7050

40 CFR 63.7555(d)(8), Minn. R.7011.7050




53

Records to Keep. The Permittee must keep records of actions taken during periods of malfunction to minimizeemissions in accordance with the general duty to minimize emissions in 40 CFR Section 63.7500(a)(3), includingcorrective actions to restore the malfunctioning boiler, air pollution control, or monitoring equipment to its normalor usual manner of operation.

54

If a malfunction occurred during the reporting period, the report must include the number, duration, and a briefdescription for each type of malfunction which occurred during the reporting period and which caused or mayhave caused any applicable emission limitation to be exceeded. The report must also include a description ofactions taken by the Permittee during a malfunction of a boiler, process heater, or associated air pollution controldevice or CMS to minimize emissions in accordance with Section 63.7500(a)(3), including actions taken tocorrect the malfunction.

55

The Permittee must comply with all applicable requirements of 40 CFR pt. 63, subp A, as follows:63.4(b), 63.5(b)(4), 63.5(b)(6), 63.6(f)(2-3), 63.8(a)(2), 63.8(c)(1-8), 63.8(d), 63.8(e), 63.8(g), 63.9(f), 63.9(g),63.9(h), 63.9(j), 63.10(a), 63.10(b)(1), 63.10(b)(2)(i), 63.10(b)(2)(iii), 63.10(b)(2)(vi-xiv), 63.10(c), 63.10(d)(1),63.10(d)(4), 63.10(e)(1-2), 63.10(e)(3)(i-vii), and 63.10(e)(4).A copy of 40 CFR pt. 63, subp. A is included in Appendix J.

If the standard changes or upon adoption of a new or amended federal applicable requirement, and if there aremore than 3 years remaining in the permit term, the Permittee shall file an application for an amendment withinnine months of promulgation of the applicable requirement, pursuant to Minn. R. 7007.0400, subp. 3.

COMG 14(GP432)

1

Subject Items subject to 40 CFR pt. 63, subp. S: EQUI 2, EQUI 3, EQUI 9, EQUI 13, EQUI 15, EQUI 16, EQUI31, EQUI 32, EQUI 33, EQUI 34, EQUI 36, EQUI 37, EQUI 44, EQUI 64, EQUI 65, EQUI 66, EQUI 67, EQUI 71,EQUI 950, EQUI 951, EQUI 952, EQUI 956, EQUI 957, EQUI 958, EQUI 959, EQUI 961, EQUI 966, EQUI 967,EQUI 968, EQUI 972, EQUI 973, EQUI 974, EQUI 975, EQUI 976, EQUI 977, EQUI 978, EQUI 979, EQUI 938,EQUI 939, TREA 13, TREA 16, TREA 17, TREA 18, TREA 19. The Permittee must submit notification according to 40 CFR Section 63.9(b) if the Permittee constructs orreconstructs a source such that the source becomes an affected source subject to a standard.

2

At all times, the owner or operator must operate and maintain any affected source, including associated airpollution control equipment and monitoring equipment, in a manner consistent with safety and good air pollutioncontrol practices for minimizing emissions. Determination of whether such operation and maintenanceprocedures are being used will be based on information available to the Administrator which may include, but isnot limited to, monitoring results, review of operation and maintenance procedures, review of operation andmaintenance records, and inspection of the source.

3

Standards for Enclosures and Closed-vent Systems: Each enclosure shall maintain negative pressure at eachenclosure or hood opening as demonstrated by procedures specified in 40 CFR Section 63.457(e). Eachenclosure or hood opening closed during the initial performance test specified in 40 CFR Section 63.457(a) shallbe maintained in the same closed and sealed position as during the performance test at all times except whennecessary to use the opening for sampling, inspection, maintenance, or repairs. Each component of the closed-vent system used to comply with 40 CFR Section 63.443(c) and 63.445(b) that isoperated at positive pressure and located prior to a control device shall be designed for and operated with nodetectable leaks as indicated by an instrument reading of less than 500 ppm by volume above background, asmeasured by the procedures in 40 CFR Section 63.457(d). Each bypass line in the closed-vent system that could divert vent streams containing HAP to the atmospherewithout meeting the emission limitations in 40 CFR Section 63.443 or 63.445 shall comply with either of the foll..

4

Performance tests shall be conducted under such conditions as the Administrator specifies to the owner oroperator based on representative performance of the affected source for the period being tested. Upon request,the owner or operator shall make available to the Administrator such records as may be necessary to determinethe conditions of performance tests.

5

To establish or reestablish the value for each operating parameter required to be monitored under paragraphs(b) through (j), (l), and (m) of 63.453 or to establish appropriate parameters for paragraphs (f), (i), (j)(2), and (m)of 63.453, each owner or operator shall use the following procedures:Provide for the Administrator's approval the rationale for the selected operating parameter value, and monitoringfrequency, and averaging time. Include all data and calculations used to develop the value and a description ofwhy the value, monitoring frequency, and averaging time demonstrate continuous compliance with theapplicable emission standard.

6 Monitoring Requirements for Enclosure and Closed-vent Systems: 1) For each enclosure opening, a visual inspection of the closure mechanism specified in 40 CFR Section63.450(b) shall be performed at least once every calendar month with at least 21 days elapsed betweeninspections to ensure the opening is maintained in the closed position and sealed. 2) Each closed-vent system required by 40 CFR Section 63.450(a) shall be visually inspected at least onceevery calendar month with at least 21 days elapsed between inspections and at other times as requested by theAdministrator. The visual inspection shall include inspection of ductwork, piping, enclosures and connections tocovers for visible evidence of defects. 3) For positive pressure closed-vent systems or portions of closed-vent systems, demonstrate no detectableleaks as specified in 40 CFR Section 63.450(c) measured initially and annually by the procedures in 40 CFRSection 63.457(d)...

40 CFR 63.7550(c)(5)(xiii), Minn. R.7011.7050

40 CFR 63.7565, 40 CFR pt. 63, subp.A , Minn. R. 7007.0400, subp. 3, Minn.R. 7007.1150-7007.1500, Minn. R.7011.7000

40 CFR 63.5(b)(4), Minn. R. 7011.7000

40 CFR 63.453(q), Minn. R. 7011.7700

40 CFR 63.450(b), Minn. R. 7011.7700

40 CFR 63.457(o), Minn. R. 7011.7700

40 CFR 63.453(n)(4)




5

To establish or reestablish the value for each operating parameter required to be monitored under paragraphs(b) through (j), (l), and (m) of 63.453 or to establish appropriate parameters for paragraphs (f), (i), (j)(2), and (m)of 63.453, each owner or operator shall use the following procedures:Provide for the Administrator's approval the rationale for the selected operating parameter value, and monitoringfrequency, and averaging time. Include all data and calculations used to develop the value and a description ofwhy the value, monitoring frequency, and averaging time demonstrate continuous compliance with theapplicable emission standard.

6

Monitoring Requirements for Enclosure and Closed-vent Systems: 1) For each enclosure opening, a visual inspection of the closure mechanism specified in 40 CFR Section63.450(b) shall be performed at least once every calendar month with at least 21 days elapsed betweeninspections to ensure the opening is maintained in the closed position and sealed. 2) Each closed-vent system required by 40 CFR Section 63.450(a) shall be visually inspected at least onceevery calendar month with at least 21 days elapsed between inspections and at other times as requested by theAdministrator. The visual inspection shall include inspection of ductwork, piping, enclosures and connections tocovers for visible evidence of defects. 3) For positive pressure closed-vent systems or portions of closed-vent systems, demonstrate no detectableleaks as specified in 40 CFR Section 63.450(c) measured initially and annually by the procedures in 40 CFRSection 63.457(d)...

7

Recordkeeping of malfunctions. The owner or operator must maintain the following records of malfunctions:(1) Records of the occurrence and duration of each malfunction of operation (i.e., process equipment) or the airpollution control and monitoring equipment.(2) Records of actions taken during periods of malfunction to minimize emissions in accordance with 63.453(q),including corrective actions to restore malfunctioning process and air pollution control and monitoring equipmentto its normal or usual manner of operation.

8

Site-Specific Inspection Plan: The Permittee shall prepare and maintain a site-specific inspection plan for eachapplicable enclosure opening, closed-vent system, and closed collection system. The Plan shall include adrawing or schematic of the components of applicable affected equipment. The Permittee shall record theinformation described in 40CFR Section 63.454(b) for each inspection.

9

Malfunction reporting requirements. If a malfunction occurred during the reporting period, the report must includethe number, duration and a brief description for each type of malfunction which occurred during the reportingperiod and which caused or may have caused any applicable emission limitation to be exceeded. The reportmust also include a description of actions taken by an owner or operator during a malfunction of an affectedsource to minimize emissions in accordance with 40 CFR Section 63.453(q), including actions taken to correct amalfunction.

10

The Permittee must comply with all applicable requirements of 40 CFR pt. 63, subp A, as follows:63.4(b), 63.5(b)(6), 63.6(f)(2-3), 63.7(b), 63.7(c)(2-3), 63.7(d), 63.7(e)(2-3), 63.7(g), 63.7(h), 63.8(a)(2),63.8(b)(1), 63.8(c)(1)(i-ii), 63.8(c)(2-3), 63.8(c)(6), 63.8(c)(7)(i-ii), 63.8(c)(8), 63.8(d)(1-3), 63.8(e), 63.8(f)(1-5),63.8(g), 63.9(e), 63.9(g)(1), 63.9(h), 63.9(j), 63.10(a), 63.10(b)(1), 63.10(b)(2)(iii), 63.10(b)(2)(vi-xiv), 63.10(c)(1),63.10(c)(5)-(8), 63.10(c)(12)-(14), 63.10(d)(2), 63.10(d)(4), 63.10(e)(1-2(i)), and 63.10(e)(3)(i-vii).A copy of 40 CFR pt. 63, subp. A is included in Appendix J.


COMG 15(GP433)

1

Subject Items subject to 40 CFR pt. 63, subp. MM: EQUI 9, EQUI 13, EQUI 945, TREA 1, TREA 2, TREA 3,TREA 4, TREA 15, TREA 16, TREA 17.The Permittee must submit notification according to 40 CFR Section 63.9(b) if the Permittee constructs orreconstructs a source such that the source becomes an affected source subject to a standard.

2The owner or operator complying through the use of an NDCE recovery furnace equipped with a dry ESPsystem is not required to conduct any performance testing to demonstrate compliance with the gaseous organicHAP standard.

3 See 40 CFR Section 63.860 for applicability requirements.

40 CFR 63.453(k), Minn. R. 7011.7700

40 CFR 63.454(g), Minn. R. 7011.7700

40 CFR 63.454(b), Minn. R. 7011.7700

40 CFR 63.455(g), Minn. R. 7011.7700

40 CFR pt. 63, subp. A, 40 CFR pt. 63,subp. S, Minn. R. 7007.0400, subp. 3,Minn. R. 7007.1150-7007.1500, Minn.R. 7011.7000

40 CFR 63.5(b)(4), Minn. R. 7011.7000

40 CFR 63.865(c)(1), Minn. R.7011.7700




2

The owner or operator complying through the use of an NDCE recovery furnace equipped with a dry ESPsystem is not required to conduct any performance testing to demonstrate compliance with the gaseous organicHAP standard.

3 See 40 CFR Section 63.860 for applicability requirements.

4

Excess Emissions Report: The Permittee shall submit excess emission/downtime report : Due semiannually atleast. The Permittee must report any/all excess emissions quarterly within 30 days following the end of thecalendar quarter if measured parameters meet any of the conditions specified in paragraph (k)(1) or (2) of 40CFR Section 63.864. The report must contain the required elements specified in 40 CFR Section 63.10(c).Reporting excess emissions below the violation thresholds of 40 CFR Section 63.864(k) does not constitute aviolation of the Subpart MM standard. When no excess emissions have occurred, the Permittee shall submit asemi-annual report stating that no excess emissions have occurred during the reporting period. Subpart MMexcess emission reports may be combined with Subpart S semi-annual excess emission reports.

5

The Permittee must comply with all applicable requirements of 40 CFR pt. 63, subp A, as follows:63.4(b), 63.5(b)(6), 63.6(e)(1)(i-ii), 63.6(e)(3(i)), 63.6(e)(3)(iii-ix), 63.6(f)(1-3), 63.6(h)(1-2), 63.6(h)(4-9), 63.7(b),63.7(c)(2-3), 63.7(d), 63.7(e)(1-3), 63.7(g), 63.7(h), 63.8(a)(2), 63.8(b)(1-2), 63.8(c)(1-6), 63.8(c)(7)(i-ii),63.8(c)(8), 63.8(d), 63.8(e), 63.8(g), 63.9(e), 63.9(g), 63.9(h), 63.9(j), 63.10(a), 63.10(b)(1-2), 63.10(c),63.10(d)(1), 63.10(d)(3-4), 63.10(d)(5)(i-ii), 63.10(e)(1-2), 63.10(e)(3)(i-vii), and 63.10(e)(4). A copy of 40 CFRpt. 63, subp. A is included in Appendix J.


COMG 16(GP434)

1

Subject Items subject to 40 CFR pt. 63, subp. ZZZZ: EQUI 941, EQUI 942, and EQUI 943.If the permittee has an existing non-emergency CI stationary RICE with a site rating of more than 500 brake HPlocated at a major source of HAP emissions, an existing stationary CI RICE with a site rating of less than orequal to 500 brake HP located at a major source of HAP emissions, or an existing stationary CI RICE located atan area source of HAP emissions, the permittee must comply with the applicable emission limitations, operatinglimitations, and other requirements no later than May 3, 2013. If the permittee has an existing stationary SI RICEwith a site rating of less than or equal to 500 brake HP located at a major source of HAP emissions, or anexisting stationary SI RICE located at an area source of HAP emissions, the permittee must comply with theapplicable emission limitations, operating limitations, and other requirements no later than October 19, 2013.

2If the permittee owns or operates an existing stationary RICE with a site rating of equal to or less than 500 brakeHP located at a major source of HAP emissions, the permittee must comply with the emission limitations andother requirements in Table 2c to this subpart which apply to the permittee.

3

For each emergency stationary CI RICE and black start stationary CI RICE, the Permittee must meet thefollowing requirements, except during periods of startup:a. Change oil and filter every 500 hours of operation or annually, whichever comes first.b. Inspect air cleaner every 1,000 hours of operation or annually, whichever comes first, and replace asnecessary;c. Inspect all hoses and belts every 500 hours of operation or annually, whichever comes first, and replace asnecessary.

During periods of startup, the Permittee must minimize the engine's time spent at idle and minimize the engine'sstartup time at startup to a period needed for appropriate and safe loading of the engine, not to exceed 30minutes, after which time the non-startup emission limitations apply.

4

For each emergency stationary SI RICE and black start stationary SI RICE, the Permittee must meet thefollowing requirement, except during periods of startup:a. Change oil and filter every 500 hours of operation or annually, whichever comes first;b. Inspect spark plugs every 1,000 hours of operation or annually, whichever comes first, and replace asnecessary;c. Inspect all hoses and belts every 500 hours of operation or annually, whichever comes first, and replace asnecessary.


5 If an emergency engine is operating during an emergency and it is not possible to shut down the engine in orderto perform the work practice requirements on the schedule required in Table 2c of this subpart, or if performingthe work practice on the required schedule would otherwise pose an unacceptable risk under federal, state, orlocal law, the work practice can be delayed until the emergency is over or the unacceptable risk under federal,state, or local law has abated. The work practice should be performed as soon as practicable after theemergency has ended or the unacceptable risk under federal, state, or local law has abated. Sources mustreport any failure to perform the work practice on the schedule required and the federal, state or local law underwhich the risk was deemed unacceptable.

Sources have the option to utilize an oil analysis program as described in 63.6625(i) or (j) in order to extend thespecified oil change requirement in Table 2c of subpart ZZZZ.

40 CFR 63.860, Minn. R. 7011.7700

40 CFR 63.867(c), Minn. R. 7007.0800,subp. 5, Minn. R. 7011.7700

40 CFR pt. 63, subp. A, 40 CFR pt. 63,subp. MM, Minn. R. 7007.0400, subp.3, Minn. R. 7007.1150-7007.1500,Minn. R. 7011.7000

40 CFR 63.6595(a), Minn. R.7011.2305, Minn. R. 7011.2310

40 CFR 63.6602, Minn. R. 7011.2305,Minn. R. 7011.2310

40 CFR 63.6602, 40 CFR pt. 63, subp.ZZZZ (Table 2c), Minn. R. 7011.2305,Minn. R. 7011.2310





4

For each emergency stationary SI RICE and black start stationary SI RICE, the Permittee must meet thefollowing requirement, except during periods of startup:a. Change oil and filter every 500 hours of operation or annually, whichever comes first;b. Inspect spark plugs every 1,000 hours of operation or annually, whichever comes first, and replace asnecessary;c. Inspect all hoses and belts every 500 hours of operation or annually, whichever comes first, and replace asnecessary.


5

If an emergency engine is operating during an emergency and it is not possible to shut down the engine in orderto perform the work practice requirements on the schedule required in Table 2c of this subpart, or if performingthe work practice on the required schedule would otherwise pose an unacceptable risk under federal, state, orlocal law, the work practice can be delayed until the emergency is over or the unacceptable risk under federal,state, or local law has abated. The work practice should be performed as soon as practicable after theemergency has ended or the unacceptable risk under federal, state, or local law has abated. Sources mustreport any failure to perform the work practice on the schedule required and the federal, state or local law underwhich the risk was deemed unacceptable.

Sources have the option to utilize an oil analysis program as described in 63.6625(i) or (j) in order to extend thespecified oil change requirement in Table 2c of subpart ZZZZ.

6

a) The Permittee must be in compliance with the emission limitations, operating limitations, and otherrequirements in this subpart that apply to you at all times.

(b) At all times, the Permittee must operate and maintain any affected source, including associated air pollutioncontrol equipment and monitoring equipment, in a manner consistent with safety and good air pollution controlpractices for minimizing emissions. The general duty to minimize emissions does not require the Permittee tomake 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 oninformation available to the Administrator which may include, but is not limited to, monitoring results, review ofoperation and maintenance procedures, review of operation and maintenance records, and inspection of thesource.

7

(a) The Permittee must demonstrate continuous compliance with each emission limitation, operating limitation,and other requirements in Tables 1a and 1b, Tables 2a and 2b, Table 2c, and Table 2d to this subpart that applyto you according to methods specified in Table 6 to this subpart.

(b) The Permittee must report each instance in which the Permittee did not meet each emission limitation oroperating limitation in Tables 1a and 1b, Tables 2a and 2b, Table 2c, and Table 2d to this subpart that apply toyou. These instances are deviations from the emission and operating limitations in this subpart. Thesedeviations must be reported according to the requirements in 63.6650.

8

For each existing emergency and black start stationary RICE less than or equal to 500 HP located at a majorsource of HAPs, complying with the requirement to Work or Management practices, the Permittee mustdemonstrate continuous compliance by: i. Operating and maintaining the stationary RICE according to the manufacturer's emission-related operationand maintenance instructions; or ii. Develop and follow a maintenance plan which must provide to the extent practicable for the maintenance andoperation of the engine in a manner consistent with good air pollution control practice for minimizing emissions.

9

If the Permittee owns or operates an emergency stationary RICE, the Permittee must operate the emergencystationary RICE according to the requirements in paragraphs (f)(1) through (4) of this section. In order for theengine to be considered an emergency stationary RICE under this subpart, any operation other than emergencyoperation, maintenance and testing, emergency demand response, and operation in non-emergency situationsfor 50 hours per year, as described in paragraphs (f)(1) through (4) of this section, is prohibited. If the Permitteedoes not operate the engine according to the requirements in paragraphs (f)(1) through (4) of this section, theengine will not be considered an emergency engine under this subpart and must meet all requirements fornon-emergency engines.

(1) There is no time limit on the use of emergency stationary RICE in emergency situations. ..

10

a) If the Permittee must comply with the emission and operating limitations, the Permittee must keep the recordsdescribed in paragraphs (a)(1) through (a)(5), (b)(1) through (b)(3) and (c) of this section.

(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 CFR63.6605(b), including corrective actions to restore malfunctioning process and air pollution control andmonitoring equipment to its normal or usual manner of operation.

(d) The Permittee must keep the records required in Table 6 of this subpart to show continuous compliance witheach emission or operating limitation that applies...

11

a) The Permittee's records must be in a form suitable and readily available for expeditious review according to40 CFR 63.10(b)(1).

(b) As specified in 40 CFR 63.10(b)(1), the Permittee must keep each record for 5 years following the date ofeach 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 yearsafter the date of each occurrence, measurement, maintenance, corrective action, report, or record, according to40 CFR 63.10(b)(1).

12 The Permittee must also report each instance in which the applicable requirements were not met in Table 8(General Provisions) to this subpart.


40 CFR 63.6605, Minn. R. 7011.2305,Minn. R. 7011.2310

40 CFR 63.6640(a)(b), Minn. R.7011.2305, Minn. R. 7011.2310

40 CFR pt. 63, subp. ZZZZ(Table 6),Minn. R. 7011.2305, Minn. R.7011.2310

40 CFR 63.6640(f), Minn. R.7011.2305, Minn. R. 7011.2310

40 CFR 63.6655, Minn. R. 7011.2305,Minn. R. 7011.2310

40 CFR 63.6660, Minn. R. 7011.2305,Minn. R. 7011.2310




11

a) The Permittee's records must be in a form suitable and readily available for expeditious review according to40 CFR 63.10(b)(1).

(b) As specified in 40 CFR 63.10(b)(1), the Permittee must keep each record for 5 years following the date ofeach 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 yearsafter the date of each occurrence, measurement, maintenance, corrective action, report, or record, according to40 CFR 63.10(b)(1).

12 The Permittee must also report each instance in which the applicable requirements were not met in Table 8(General Provisions) to this subpart.

13

If the Permittee owns or operates any of the following stationary RICE, the Permittee must operate and maintainthe stationary RICE and after-treatment control device (if any) according to the manufacturer's emission-relatedwritten instructions or develop a maintenance plan which must provide to the extent practicable for themaintenance and operation of the engine in a manner consistent with good air pollution control practice forminimizing emissions:

(1) An existing stationary RICE with a site rating of less than 100 HP located at a major source of HAPemissions;

(2) An existing emergency or black start stationary RICE with a site rating of less than or equal to 500 HPlocated at a major source of HAP emissions.

14

If the Permittee owns or operates an existing emergency stationary RICE with a site rating of less than or equalto 500 brake HP located at a major source of HAP emissions or an existing emergency stationary RICE locatedat an area source of HAP emissions, the Permittee must install a non-resettable hour meter if one is not alreadyinstalled.

15

The Permittee must comply with all applicable requirements of 40 CFR pt. 63, subp A, as follows:63.4(b), 63.5(b)(4), 63.5(b)(6), 63.6(f)(2-3), 63.7(d), 63.7(e)(3), 63.7(g), 63.7(h), 63.8(a)(2), 63.8(b)(1-2), 63.8(c),63.8(c)(7)(i-ii), 63.8(c)(8), 63.8(d), 63.8(g), 63.9(j), 63.10(a), 63.10(b)(1), 63.10(b)(2)(vi-xiv), 63.10(c),63.10(d)(1), 63.10(d)(4), 63.10(e)(1-2(i)), and 63.10(e)(3)(i-vii). A copy of 40 CFR pt. 63, subp. A is included inAppendix J.


16 Opacity <= 20 percent opacity once operating temperatures have been attained. This condition applies to eachengine in COMG 16.

17 Sulfur Dioxide <= 0.50 pounds per million Btu heat input.

18 Sulfur Dioxide <= 0.0015 pounds per million Btu heat input This limit is effective on January 31, 2018.

20 Hours of Operation: The Permittee shall maintain documentation on site that the unit is an emergency generatorby design that qualifies under the U.S. EPA memorandum entitled "Calculating Potential to Emit (PTE) forEmergency Generators" dated September 6, 1995, limiting operation to 500 hours per year.

40 CFR 63.6640(e), Minn. R.7011.2305, Minn. R. 7011.2310

40 CFR 63.6625(e), Minn. R.7011.2305, Minn. R. 7011.2310

40 CFR 63.6625(f), Minn. R.7011.2305, Minn. R. 7011.2310

40 CFR 63.6665, 40 CFR pt. 63, subp.A, Minn. R. 7007.0400, subp. 3, Minn.R. 7007.1150-7007.1500, Minn. R.7011.7000

Minn. R. 7011.2300, subp. 1

Minn. R. 7011.2300, subp. 2(A)

Minn. R. 7011.2300, subp. 2(B)




18 Sulfur Dioxide <= 0.0015 pounds per million Btu heat input This limit is effective on January 31, 2018.

20Hours of Operation: The Permittee shall maintain documentation on site that the unit is an emergency generatorby design that qualifies under the U.S. EPA memorandum entitled "Calculating Potential to Emit (PTE) forEmergency Generators" dated September 6, 1995, limiting operation to 500 hours per year.

21 The Permittee shall keep records of fuel type and usage on a monthly basis.

22 Fuel Supplier Certification: The Permittee shall obtain and maintain a fuel supplier certification for each shipmentof diesel fuel oil, certifying that the sulfur content does not exceed 0.050 percent by weight.

COMG 19 1 Opacity <= 20 percent opacity.

2Particulate Matter <= 0.30 grains per dry standard cubic foot of exhaust gas unless required to further reduceemissions to comply with the less stringent limit of either Minn. R. 7011.0730 or Minn. R. 7011.0735.The units in COMG 19 are not expected to emit particulate matter.

EQUI 9(EU320)

1The Permittee shall limit emissions of Particulate Matter <= 27.0 pounds per hour 3-hour average, asdetermined by performance test. This is based on an EPA approved limit from a letter dated September 29,2008.

2The Permittee shall limit emissions of Particulate Matter <= 0.044 grains per dry standard cubic foot 3-houraverage, as determined by performance test, @ 8% O2. This is the limit for both NSPS 40 CFR pt. 60, subp. BB and NESHAP 40 CFR pt. 63, subp. MM.

3 The Permittee shall limit emissions of PM < 10 micron <= 19.2 pounds per hour 3-hour average, as determinedby performance test. This is based on an EPA approved limit from a letter dated September 29, 2008.

Minn. R. 7007.0800, subps. 4-5

Minn. R. 7007.0800, subp. 5

Minn. R. 7007.0800, subps. 4-5

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

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

40 CFR 63.862(a)(1)(ii), Title ICondition: 40 CFR 52.21(j)(BACT) &Minn. R. 7007.3000

40 CFR 60.282(a)(i), 40 CFR63.862(a)(1)(i), Minn. R. 7011.2450,Minn. R. 7011.7700



Subject ItemID Seq. # RequirementEQUI 9(EU320)

2

The Permittee shall limit emissions of Particulate Matter <= 0.044 grains per dry standard cubic foot 3-houraverage, as determined by performance test, @ 8% O2. This is the limit for both NSPS 40 CFR pt. 60, subp. BB and NESHAP 40 CFR pt. 63, subp. MM.


4 The Permittee shall limit Opacity <= 35 percent opacity 6-minute average (NSPS 40 CFR pt. 60, supb. BB limit).

5The Permittee shall limit emissions of Sulfur Dioxide <= 200 tons per year 12-month rolling sum. The Permitteeshall use the emission factor derived from the most recent performance test and the monthly productionthroughput.

6 The Permittee shall limit emissions of Sulfur Dioxide <= 106.2 pounds per hour 3-hour average, as determinedby performance test. Compliance for this limit is demonstrated with a performance test.

7 The Permittee shall limit emissions of Nitrogen Oxides <= 110 pounds per hour 30-day rolling average. This isequivalent to 80 ppm on a dry basis, corrected to 8% oxygen.

8 The Permittee shall limit emissions of Carbon Monoxide <= 538 pounds per hour 24-hour rolling average. Thisis equivalent to 600 ppm on a dry basis, corrected to 8% oxygen.

9The Permittee shall limit emissions of Volatile Organic Compounds <= 31.3 pounds per hour 3-hour average, asdetermined by performance test, measured as carbon, excluding methane. (this limit is based on emission rateof 0.6 lb/salt cake free, bone dry tons of black liquor solids).

10 The Permittee shall limit emissions of Carbon Monoxide <= 2289 tons per year 12-month rolling average.

Title I Condition: 40 CFR52.21(j)(BACT) & Minn. R. 7007.3000

40 CFR 60.282(a)(ii), Minn. R.7011.2450









9

The Permittee shall limit emissions of Volatile Organic Compounds <= 31.3 pounds per hour 3-hour average, asdetermined by performance test, measured as carbon, excluding methane. (this limit is based on emission rateof 0.6 lb/salt cake free, bone dry tons of black liquor solids).

10 The Permittee shall limit emissions of Carbon Monoxide <= 2289 tons per year 12-month rolling average.

11

The Permittee shall limit emissions of Sulfur - Total Reduced including H2S <= 5 parts per million 12-houraverage, calculated on a dry basis and corrected to 8% oxygen.

This is the limit for both BACT and NSPS 40 CFR pt. 60, subp. BB.

13 The Permittee shall limit Sulfur Content of Fuel <= 0.050 percent by weight distillate oil sulfur content.

14 Fuels burned: The Permittee shall burn Natural Gas; HVLC NCGs and black liquor solids (BLS) (virgin bonedried basis) and BLS blended with distillate oil (#1 or #2) are also combusted in the recovery furnace.

15

The Permittee shall limit Process Throughput <= 1595 tons per day of virgin black liquor solids (virgin bone driedbasis), calculated on a twelve-hour block average, unless a new limit is set pursuant to Minn. R. 7017.2025,subp. 3, based on the most recent MPCA approved performance test where compliance was demonstrated.

The twelve-hour block average shall be calculated by dividing the total weight by the total operating time in eachtwelve-hour block. Down time of 15 or more minutes is not to be included as operating time.

The Black Liquor Solids Production limit located at the TFAC level also applies at all times.

16 The Permittee shall limit Process Throughput <= 30.0 gallons per hour 12-hour average (calculated on atwelve-hour block average) of distillate oil (#1 or #2).

17

The Administrator will not consider periods of excess emissions to be indicative of a violation provided that thepercent of the total number of possible contiguous periods of excess emissions in a quarter (excluding periodsof startup, shutdown, or malfunction and periods when the facility is not operating) during which excessemissions occur does not exceed: 1) One percent for TRS emissions from recovery furnaces; or 2) Six percent for average opacities from recovery furnaces.

18 Recordkeeping: The Permittee shall record and maintain records of the black liquor solids firing rate in units ofton/day on a daily basis.

Title I Condition: Avoid majormodification under 40 CFR 52.21(b)(2)& Minn. R. 7007.3000

40 CFR 60.283(a)(2), Minn. R.7011.2450, Title I Condition: 40 CFR52.21(j)(BACT) & Minn. R. 7007.3000

Minn. R. 7007.0800, subp. 2

Title I Condition: 40 CFR52.21(j)(BACT) & Minn. R. 7007.3000,Title I Condition: 40 CFR52.21(k)(modeling) & Minn. R.7007.3000

Minn. R. 7017.2025, subp. 3

Minn. R. 7007.0800, subps. 4-5, Title ICondition: 40 CFR 52.21(j)(BACT) &Minn. R. 7007.3000

40 CFR 60.284, Minn. R. 7011.2450




17

The Administrator will not consider periods of excess emissions to be indicative of a violation provided that thepercent of the total number of possible contiguous periods of excess emissions in a quarter (excluding periodsof startup, shutdown, or malfunction and periods when the facility is not operating) during which excessemissions occur does not exceed: 1) One percent for TRS emissions from recovery furnaces; or 2) Six percent for average opacities from recovery furnaces.

18 Recordkeeping: The Permittee shall record and maintain records of the black liquor solids firing rate in units ofton/day on a daily basis.

19Reporting: The Permittee shall notify the Administrator before the black liquor solids firing rate for any kraft orsoda recovery furnace during any 24-hour averaging period is increased by more than 10 percent above thelevel measured during the most recent performance test.

20

Monthly Recordkeeping -- Sulfur Dioxide and Carbon Monoxide Emissions.

By the 15th of the month, the Permittee shall calculate and record the following: 1) The total SO2 and CO emissions for the previous calendar month 2) The 12-month rolling sum of SO2 and CO emissions for the previous 12-month period by summing themonthly emissions data for the previous 12 months.

21 The Permittee shall record total distillate oil usage in gallons once every 12 hours.

22

The Permittee shall record and calculate every 12 hours the 12 hour block average of distillate processthroughput, in gallons/hour, of distillate oil that was burned in the recovery furnace to verify that the distillateprocess throughput was less than or equal to 30.0 gallons/hour using a 12-hour Block Average. The Permitteeshall maintain these records for a period of 5 years..

23Fuel Supplier Documentation: The Permittee shall obtain and maintain fuel supplier documentation for eachshipment of fuel distillate oil (#1 and #2), documenting that the sulfur content does not exceed 0.050% byweight. Records shall be maintained for 5 years.

24 Emissions Monitoring: The Permittee shall use a COMS to measure Opacity emissions from EQUI 9.

25 ESP Monitoring: The COMS for EQUI 9 shall be used to assess proper operation of this ESP (TREA 1).

40 CFR 63.866(c)(1), Minn. R.7007.0800, subp. 5, Minn. R.7011.7700

40 CFR 63.867(b)(3)(iv), Minn. R.7011.7700

Minn. R. 7007.0800, subps. 4-5




40 CFR 63.865(c)(1), 40 CFR pt. 64,Minn. R. 7017.1006, Title I Condition:40 CFR 52.21(j)(BACT) & Minn. R.7007.3000





25 ESP Monitoring: The COMS for EQUI 9 shall be used to assess proper operation of this ESP (TREA 1).

26

SSM Excess Emissions Report: Report any/all excess emissions quarterly within 30 days following the end ofthe calendar quarterly. The report must contain the required elements specified in 40 CFR Section 63.10(c).Reporting excess emissions below the violation thresholds of 63.864(k) does not constitute a violation of theSubpart MM standard. When no excess emissions have occurred, the Permittee shall submit a semi-annualreport stating that no excess emissions have occurred during the reporting period. Subpart MM excessemission reports may be combined with Subpart S semi-annual excess emission reports.

27On-going compliance provisions. Recovery Furnace units are required to implement corrective action if themonitoring exceedances, when the average of ten consecutive 6-minute averages result in a measurementgreater than 20 percent opacity.

28 The Recovery Furnace is in violation of the standards of 63.862 if the opacity is greater than 35 percent for 6percent or more of the operating time within any quarterly period.

29

The Permittee shall install, calibrate, maintain and operate a continuous monitoring system for measuring andrecording, Nitrogen Oxide emissions, Carbon Monoxide emissions, Total Reduced Sulfur emissions, and eitherOxygen or Carbon Dioxide.(Monitoring associated with Title I emission limit).

30

Alternative Biomass Fuel Testing Authorization: The Permittee is authorized to conduct operational test burns ofthe following biomass fuels: BLS Soap Tall Oil, Wastewater Treatment Residual, Glycerin or glycerol, herbs,nuts; vegetable oils; crop field residue or field processing residues; shells, husks, seeds, dust, screenings andother agricultural processing residues; cultivated grasses or grass by products and leaves. Acceptable biomassfuels do not include wood that has been painted or pressure treated; peat; off-site generated waste oil, farmchemicals, pesticide containers, demolition waste except wood, waste from farms from an open dump, tirederived fuels, non-agricultural industrial process wastes except wood derived wastes or any material meetingthe definition of a hazardous waste.

31

Alternative Biomass Fuel Testing Requirements and Restrictions: Operational test burn will include, but not belimited to, nitrogen oxide, carbon monoxide, and opacity emission limits monitored by existing CEMs and COMs.Alternative biomass fuels will further be limited to less than 5,000 tons. Alternative test fuels will be limited toless than 25 percent of the heat input capacity of the boiler. Feasibility test burns will be monitored for NOx, CO,TRS, and opacity. If feasibility test burns prove successful, then PM, PM10, PM2.5, SO2 and VOC performancetest data will be gathered during the performance testing phase. Preliminary fuel testing will be completed toestimate the maximum HAP emissions (HCl and Hg).

32 Test burns shall consist of up to two phases - feasibility and performance testing. If an alternative biomass fuelmeets feasibility requirements (as defined by the Permittee) such that it may be proposed as an additional fuel,the Permittee may move into the performance testing phase.

40 CFR 63.865(c)(1), 40 CFR 64.7(a),Minn. R. 7007.0800, subp. 2

40 CFR 63.867(c), Minn. R. 7011.7700

40 CFR 63.864(k)(1)(i), Minn. R.7011.7700

40 CFR 63.864(k)(2)(i), Minn. R.7011.7700

40 CFR 60.45(a), 40 CFR 64.7(a),Minn. R. 7017.1006, Title I Condition:40 CFR 52.21(j)(BACT) & Minn. R.7007.3000, Title I Condition: 40 CFR52.21(o)(visibility) & Minn. R.7007.3000

Minn. R. 7007.0800, subp. 2

Minn. R. 7007.0800, subp. 2




31

Alternative Biomass Fuel Testing Requirements and Restrictions: Operational test burn will include, but not belimited to, nitrogen oxide, carbon monoxide, and opacity emission limits monitored by existing CEMs and COMs.Alternative biomass fuels will further be limited to less than 5,000 tons. Alternative test fuels will be limited toless than 25 percent of the heat input capacity of the boiler. Feasibility test burns will be monitored for NOx, CO,TRS, and opacity. If feasibility test burns prove successful, then PM, PM10, PM2.5, SO2 and VOC performancetest data will be gathered during the performance testing phase. Preliminary fuel testing will be completed toestimate the maximum HAP emissions (HCl and Hg).

32Test burns shall consist of up to two phases - feasibility and performance testing. If an alternative biomass fuelmeets feasibility requirements (as defined by the Permittee) such that it may be proposed as an additional fuel,the Permittee may move into the performance testing phase.

33

Alternative Biomass Fuel Testing Restrictions: Feasibility test burns for any alternative biomass fuel shall belimited to no more than 168 hours of operation using the fuel, and a test period not to exceed 30 days.Performance tests for any alternative biomass fuel shall be limited to no more than 168 additional hours ofoperation using the proposed fuel and a test period not to exceed 60 additional days.

34

Performance Test Plan: The permittee shall submit a performance test plan : Due 30 calendar days beforePerformance Test Date (Alternative Biomass Fuel Emission Testing submittal) of the operational and emissiontesting of a biomass fuel (emission testing will be conducted only if operational testing has been provenfeasible), the permitee shall submit a written performance test notification and test plan. The test plan shallinclude (1) the type(s) and estimated amount of biomass to be tested, (2) operating parameters and anticipatedfuel mixes during the emission testing of the boiler to be tested, (3) air pollutants that will be monitored (ie., PM,PM-10, and VOC), and (4) a testing schedule.

35

Alternative Biomass Fuel Emission Testing Notification and submittals;Pretest meeting: due 7 days before Performance TestTest Report: Due 45 days after Performance TestTest Report: CD copy due 105 days after Performance TestThe Notification, the test Plan, and Test Report may be submitted in alternative format as allowed by Minn. R.7017.2018.

36

Particulate Matter : The Permittee shall conduct a performance test : Due before 09/13/2021 every 60 months tomeasure emissions. Testing is due by the end of each 60 month period following the initial performance testdate. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp.8, using EPA Reference Methods 5 and 202, or other method approved by MPCA in the performance test planapproval.

Testing conducted during the 60 days prior to the performance test due date satisfies the performance test duedate, 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 ..

37

PM < 10 micron : The Permittee shall conduct a performance test : Due before 09/13/2021 every 60 months tomeasure emissions. Testing is due by the end of each 60 month period following the initial performance testdate. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp.8, using EPA Reference Method 201A and 202, or other method approved by MPCA in the performance testplan approval.


38

Sulfur Dioxide : The Permittee shall conduct an initial performance test : Due 365 calendar days after PermitIssuance Date to measure emissions. The performance test shall be conducted at worst case conditions asdefined at Minn. R. 7017.2025, subp. 2, using EPA Reference Method 6C, or other method approved by MPCAin the performance test plan approval.

39 Volatile Organic Compounds : The Permittee shall conduct an initial performance test : Due 1826 calendar daysafter Permit Issuance Date to measure emissions, measured as carbon, excluding methane. The performancetest shall be conducted at worst case conditions as defined at Minn. R. 7017.2025, subp. 2, using EPAReference Method 25A, or other method approved by MPCA in the performance test plan approval.

Minn. R. 7007.0800, subp. 2

Minn. R. 7007.0800, subp. 2

Minn. R. 7017.2018, Minn. R.7017.2030, subps. 1-4


40 CFR 63.865(b)(1), Minn. R.7017.2020, subp. 1, Title I Condition:40 CFR 52.21(j)(BACT ) & Minn. R.7007.3000

40 CFR 63.865(b)(1), Minn. R.7017.2020, subp. 1, Title I Condition:40 CFR 52.21(j)(BACT ) & Minn. R.7007.3000

Minn. R. 7017.2020, subp. 1, Title ICondition: 40 CFR 52.21(j)(BACT) &Minn. R. 7007.3000




38


39

Volatile Organic Compounds : The Permittee shall conduct an initial performance test : Due 1826 calendar daysafter Permit Issuance Date to measure emissions, measured as carbon, excluding methane. The performancetest shall be conducted at worst case conditions as defined at Minn. R. 7017.2025, subp. 2, using EPAReference Method 25A, or other method approved by MPCA in the performance test plan approval.

40

Sulfur Dioxide: The Permittee shall submit a test frequency plan : Due 60 calendar days after Initial PerformanceTest Date for Sulfur Dioxide. The plan shall specify a testing frequency based on the test data and MPCAguidance. Future performance tests based on 12-month, 36-month, or 60-month intervals, or as applicable, shallbe required upon written approval of the MPCA.

41

Volatile Organic Compounds: The Permittee shall submit a test frequency plan : Due 60 calendar days afterInitial Performance Test Date for VOC emissions. The plan shall specify a testing frequency based on the testdata and MPCA guidance. Future performance tests based on 12-month, 36-month, or 60-month intervals, or asapplicable, shall be required upon written approval of the MPCA.

EQUI 12(EU902)

2 Particulate Matter <= 0.30 grains per dry standard cubic foot of exhaust gas unless required to further reduceemissions to comply with the less stringent limit of either Minn. R. 7011.0730 or Minn. R. 7011.0735.

3 Opacity <= 20 percent opacity.

4 Operating Hours <= 1044 hours per year 12-month rolling sum.

5 Spray Booth Operation: The particulate filter for EQUI 12 shall be securely in place whenever paint sprayingoccurs. The filter shall be maintained and replaced according to manufacturer's specifications.

6 Monthly Recordkeeping -- spray booth operating hours

By the 15th of the month, the Permittee shall calculate and record the following: 1) The total spray booth hours of operation for the previous calendar month 2) The 12-month rolling sum of spray booth hours of operation for the previous 12-month period by summingthe monthly emissions data for the previous 12 months.




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

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

Title I Condition: Avoid majormodification under 40 CFR 52.21(b)(2)& Minn. R. 7007.3000

Title I Condition: Avoid majormodification under 40 CFR 52.21(b)(2)and Minn. R. 7007.3000




5Spray Booth Operation: The particulate filter for EQUI 12 shall be securely in place whenever paint sprayingoccurs. The filter shall be maintained and replaced according to manufacturer's specifications.

6

Monthly Recordkeeping -- spray booth operating hours

By the 15th of the month, the Permittee shall calculate and record the following: 1) The total spray booth hours of operation for the previous calendar month 2) The 12-month rolling sum of spray booth hours of operation for the previous 12-month period by summingthe monthly emissions data for the previous 12 months.

7 Reporting: The Permittee shall submit an annual report : Due annually, by the 30th of January for the previous12 monthly 12-month rolling sum calculations of spray booth operation.

EQUI 13(EU340)

1The Permittee shall limit emissions of Particulate Matter <= 12.7 pounds per hour 3-hour average, asdetermined by performance test. This is based on an EPA approved limit from a letter dated September 29,2008.

2

The Permittee shall limit emissions of Particulate Matter <= 0.066 grains per dry standard cubic foot 3-houraverage, as determined by performance test, @10% oxygen.

This is the NSPS 40 CFR pt. 60, subp. BB limit. The NESHAP 40 CFR pt. 63, subp. MM limit is 0.064 gr/dscf,however, the EPA approved the alternative limit in a letter dated September 29, 2008.


5 The Permittee shall limit emissions of Sulfur Dioxide <= 13.5 pounds per hour 3-hour average, as determined byperformance test.

6 The Permittee shall limit emissions of Nitrogen Oxides <= 34.9 pounds per hour 3-hour average, as determinedby performance test.

7 The Permittee shall limit emissions of Carbon Monoxide <= 23.7 pounds per hour 3-hour average, asdetermined by performance test.

Minn. R. 7007.0800, subps. 4-5, Title ICondition: Avoid major source under 40CFR 52.21(b)(2) & Minn. R. 7007.3000

Minn. R. 7007.0800, subp. 6

Title I Condition: 40 CFR52.21(b)(2)(i)(netting) & Minn. R.7007.3000, Title I Condition: 40 CFR52.21(k)(modeling) & Minn. R.7007.3000

40 CFR 60.282(a)(3)(i), 40 CFR63.862(a)(ii), Minn. R. 7011.2450,Minn. R. 7011.7700







6The Permittee shall limit emissions of Nitrogen Oxides <= 34.9 pounds per hour 3-hour average, as determinedby performance test.


8 The Permittee shall limit emissions of Volatile Organic Compounds <= 11.4 pounds per hour 3-hour average, asdetermined by performance test, measured as Carbon excluding methane.

9

The Permittee shall limit emissions of Sulfur - Total Reduced including H2S <= 8.0 parts per million 12-houraverage, calculated on a dry basis and corrected to 10% oxygen.

This is the limit for both BACT and NSPS 40 CFR pt. 60, subp. BB.

11

The Permittee shall limit Production <= 237 tons per day of lime, calculated on a twelve-hour block average,unless a new limit is set pursuant to Minn. R. 7017.2025, subp. 3, based on the most recent MPCA approvedperformance test where compliance was demonstrated.

The twelve-hour block average shall be calculated by dividing the total weight by the total operating time in eachtwelve-hour block. Down time of 15 or more minutes is not to be included as operating time.

12 Fuel Usage: Limited to natural gas. Low Volume High Concentration (LVHC) Non-condensable gas (NCG) isalso oxidized in the lime kiln.

13The Permittee shall calibrate, maintain and operate a continuous monitoring system for measuring and recordingthe concentration of Total Reduced Sulfur emissions on a dry basis and the percent of oxygen by volume on adry basis.

14

The Permittee shall maintain records of parameter monitoring data required under 40 CFR Section 63.864,including any period when the operating parameter levels were inconsistent with the levels established duringthe initial performance test, with a brief explanation of the cause of the deviation, the time the deviationoccurred, the time corrective action was initiated and completed, and the corrective action taken.

15 Recordkeeping: The Permittee shall record the production rate of CaO (calcium oxide or lime) in units oftons/day and maintain the records.

Title I Condition: 40 CFR52.21(j)(BACT) & Minn. R. 7007.3000,Title I Condition: 40 CFR52.21(k)(modeling)



Minn. R. 7017.2025, subp. 3, Minn. R.7017.2025, subp. 3a


40 CFR 60.284, 40 CFR 64.7(a), Minn.R. 7017.1006, Title I Condition: 40 CFR52.21(j)(BACT) & Minn. R. 7007.3000

40 CFR 63.866(c)(3), Minn. R.7011.7700




14

The Permittee shall maintain records of parameter monitoring data required under 40 CFR Section 63.864,including any period when the operating parameter levels were inconsistent with the levels established duringthe initial performance test, with a brief explanation of the cause of the deviation, the time the deviationoccurred, the time corrective action was initiated and completed, and the corrective action taken.

15 Recordkeeping: The Permittee shall record the production rate of CaO (calcium oxide or lime) in units oftons/day and maintain the records.

17

Monthly Recordkeeping -- lime production

By the 15th of the month, the Permittee shall calculate and record the amount of lime produced for the previouscalendar month.

18

NOx Emissions Calculation: The Permittee shall calculate NOx emissions on a semi-annual basis. The NOxemission factor shall be obtained from the most recent MPCA approved performance test. The NOx emissionsshall be calculated and converted to a tons/day basis for determining the total NOx emissions from the Facilityand comparison to the NOx emissions cap (COMG 5).

Lime Kiln NOx emissions (tons/day) = (MM lbs BLS/day * 1,000,000/MM * ton/2000 lbs) * (0.21 lbs/ton of BLS * ton/2000 lbs)

Note that 0.21 lbs NOx/ton of BLS produced is the relationship established during the 2012 performance test.The next performance test for NOx is scheduled to be completed before 9/5/2017.

19



20

PM < 10 micron : The Permittee shall conduct a performance test : Due before 11/06/2017 every 36 months tomeasure emissions. Testing is due by the end of each 36 month period following the initial performance testdate. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp.8, using EPA Reference Methods 210A and 202 or other method approved by MPCA in the performance testplan approval.


21

Nitrogen Oxides : The Permittee shall conduct a performance test : Due before 09/05/2017 every 60 months tomeasure emissions. Testing is due by the end of each 60 month period following the initial performance testdate. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp.8, 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 duedate, 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 testdue date satisfies this test due date requirement and will reset the performance test due date.

22

Sulfur Dioxide : The Permittee shall conduct a performance test : Due before 09/05/2017 every 60 months tomeasure emissions. Testing is due by the end of each 60 month period following the initial performance testdate. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp.8, using EPA Reference Method 6C, or other method approved by MPCA in the performance test plan approval.


23 Volatile Organic Compounds : The Permittee shall conduct a performance test : Due after 09/05/2017 every 60months to measure emissions. Testing is due by the end of each 60 month period following the initialperformance test date. The performance test shall be conducted at worst case conditions as defined at Minn. R.7017.2005, subp. 8, using EPA Reference Methods 25A/18, or other method approved by MPCA in theperformance test plan approval.


40 CFR 63.866(c)(2), Minn. R.7011.7700

Minn. R. 7007.0800, subp. 6

Minn. R. 7007.0800, subp. 6, Title ICondition: 40 CFR 52.21(j)(BACT) &Minn. R. 7007.3000, Title I Condition:40 CFR 52.21(o)(visibility) & Minn. R.7007.3000

40 CFR 63.865, Minn. R. 7017.2020,subp. 1, Title I Condition: 40 CFR52.21(k)(modeling) & Minn. R.7007.3000

40 CFR 63.865, Minn. R. 7017.2020,subp. 1, Title I Condition: 40 CFR52.21(k)(modeling) & Minn. R.7007.3000


Minn. R. 7017.2020, subp. 1, Title ICondition: 40 CFR 52.21(k)(modeling)& Minn. R. 7007.3000




22

Sulfur Dioxide : The Permittee shall conduct a performance test : Due before 09/05/2017 every 60 months tomeasure emissions. Testing is due by the end of each 60 month period following the initial performance testdate. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp.8, using EPA Reference Method 6C, or other method approved by MPCA in the performance test plan approval.


23

Volatile Organic Compounds : The Permittee shall conduct a performance test : Due after 09/05/2017 every 60months to measure emissions. Testing is due by the end of each 60 month period following the initialperformance test date. The performance test shall be conducted at worst case conditions as defined at Minn. R.7017.2005, subp. 8, using EPA Reference Methods 25A/18, or other method approved by MPCA in theperformance test plan approval.


24

Carbon Monoxide : The Permittee shall conduct a performance test : Due after 09/05/2017 every 60 months tomeasure emissions. Testing is due by the end of each 60 month period following the initial performance testdate. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp.8, using EPA Reference Method 10, or other method approved by MPCA in the performance test plan approval.


EQUI 15(EU420)

1 The Permittee shall limit emissions of Particulate Matter <= 0.60 pounds per million Btu heat input 3-houraverage, as determined by performance test. The potential to emit from the unit is 0.008 lb/MMBtu.

2 The Permittee shall limit emissions of PM < 10 micron <= 0.60 pounds per million Btu heat input 3-hour average,as determined by performance test. The potential to emit from the unit is 0.008 lb/MMBtu.

3 The Permittee shall limit Opacity <= 20 percent opacity, except for one six-minute period per hour of not morethan 60 percent Opacity.

4 The Permittee shall limit emissions of Nitrogen Oxides <= 0.20 pounds per million Btu heat input 30-day rollingaverage.

5Fuel burned: limited to natural gas. Exhaust from the sludge dryer (EQUI 24) may also vent to boiler #1.Non-condensable gas (NCG) is also oxidized in boiler #1. The amount of NCG burned in boiler #1 is limitedunder COMG 6.

6 The Permittee shall calibrate, maintain and operate a continuous monitoring system for measuring and recordingthe Nitrogen Oxide emissions, and either Oxygen or Carbon Dioxide.



Minn. R. 7011.0510, subp. 1, Title ICondition: 40 CFR52.21(b)(2)(i)(netting) & Minn. R.7007.3000, Title I Condition: 40 CFR52.21(k)(modeling) & Minn. R.7007.3000


Minn. R. 7011.0510, subp. 2

Title I Condition: 40 CFR52.21(k)(modeling) & Minn. R.7007.3000

Minn. R. 7007.3000, Title I Condition:40 CFR 52.21(j)(BACT), Title ICondition: 40 CFR 52.21(k)(modeling)




5

Fuel burned: limited to natural gas. Exhaust from the sludge dryer (EQUI 24) may also vent to boiler #1.Non-condensable gas (NCG) is also oxidized in boiler #1. The amount of NCG burned in boiler #1 is limitedunder COMG 6.

6 The Permittee shall calibrate, maintain and operate a continuous monitoring system for measuring and recordingthe Nitrogen Oxide emissions, and either Oxygen or Carbon Dioxide.

7The affected source of 40 CFR pt. 63, subp. DDDDD is the collection at a major source of all existing industrial,commercial, and institutional boilers and process heaters within a subcategory as defined in 40 CFR Section63.7575. This unit is part of the subcategory "units designed to burn gas 1 fuels."

EQUI 16(EU430)

1 The Permittee shall limit emissions of Particulate Matter <= 13.0 pounds per hour 3-hour average, asdetermined by performance test.

2 The Permittee shall limit emissions of PM < 10 micron <= 11.7 pounds per hour 3-hour average, as determinedby performance test.

3 The Permittee shall limit emissions of Front-half Particulate Matter <= 0.037 pounds per million Btu heat input3-hour average, as determined by performance test. (Filterable PM - NESHAP limit).

4 The Permittee shall limit Opacity <= 10 percent opacity 24-hour block average (NESHAP limit).

5 The Permittee shall limit emissions of Sulfur Dioxide <= 39.5 pounds per hour using 6-hour rolling average. Thislimit does not apply when NCG is being oxidized in Boiler #2.

6 The Permittee shall limit emissions of Sulfur Dioxide <= 9.4 pounds per hour 12-month rolling average. Thislimit does not apply when NCG is being oxidized in Boiler #2.

Minn. R. 7017.1006

40 CFR 63.7490



40 CFR 63.7500(a)(1), 40 CFR pt. 63,subp. DDDDD(Table 2), Minn. R.7011.7050


Title I Condition: 40 CFR52.21(j)(BACT) & Minn. R. 7007.3000,Title I Condition: 40 CFR52.21(k)(modeling) & MInn. R.1007.3000




5The Permittee shall limit emissions of Sulfur Dioxide <= 39.5 pounds per hour using 6-hour rolling average. Thislimit does not apply when NCG is being oxidized in Boiler #2.

6 The Permittee shall limit emissions of Sulfur Dioxide <= 9.4 pounds per hour 12-month rolling average. Thislimit does not apply when NCG is being oxidized in Boiler #2.

7 The Permittee shall limit emissions of Nitrogen Oxides <= 100.2 pounds per hour 30-day rolling average.

8 The Permittee shall limit emissions of Carbon Monoxide <= 800 pounds per hour 1-hour average.

9 The Permittee shall limit emissions of Carbon Monoxide <= 200 pounds per hour 12-month rolling average.

10The Permittee shall limit emissions of Carbon Monoxide <= 720 parts per million 30-day rolling average,calculated by volume on a dry basis @ 3% oxygen.(NESHAP limit).

11 The Permittee shall limit emissions of Volatile Organic Compounds <= 40.2 pounds per hour 3-hour average, asdetermined by performance test, as determined by performance test, measured as C excluding methane.

12 The Permittee shall limit emissions of Hydrochloric acid <= 0.022 pounds per million Btu heat input 3-houraverage, as determined by performance test.

13 The Permittee shall limit emissions of Mercury <= 5.7E-06 pounds per million Btu heat input 3-hour average, asdetermined by performance test.



Title I Condition: 40 CFR52.21(j)(BACT) & Minn. R. 7007.3000,Title I Condition: 40 CFR52.21(k)(modeling)

Title I Condition: 40 CFR52.21(j)(BACT) & Minn. R. 7007.3000,Title I Condition: 40 CFR52.21(k)(modeling) & MInn. R.7007.3000







12The Permittee shall limit emissions of Hydrochloric acid <= 0.022 pounds per million Btu heat input 3-houraverage, as determined by performance test.

13 The Permittee shall limit emissions of Mercury <= 5.7E-06 pounds per million Btu heat input 3-hour average, asdetermined by performance test.

14Fuel Burned: Fuels to be burned are limited to bark, wood refuse, wastewater treatment sludge, paper, andnatural gas. Non-condensable gas (NCG) is also oxidized in Boiler #2. The amount of NCG burned in Boiler #2is limited under COMG 6.

15 Fuel Usage <= 27010 tons per month 12-month rolling average. The fuel usage limit is for combined total ofbark, wood refuse, paper, and sludge and shall be expressed in units of green tons per month.

16 Fuel Usage <= 5193 tons per month 12-month rolling average (SLUDGE USAGE LIMIT).

17

Monthly Recordkeeping: By the 15th of the month, the Permittee shall calculate and record the 12-month rolling average for the previous12-month period by calculating the average monthly fuel usage for the previous 12 months for: 1) combined fuel usage (bark, wood refuse, paper, and sludge) 2) sludge usage.

18

Fuel Usage <= 39.7 tons per hour of total bark, wood refuse, paper, and sludge, calculated on a six-hour blockaverage. This limit is in effect unless a new limit is set pursuant to Minn. R. 7017.2025, subp. 3, based on themost recent MPCA approved performance test where compliance was demonstrated.

The six-hour block average shall be calculated by dividing the total weight by the total operating time in eachsix-hour block. Down time of 15 or more minutes is not to be included as operating time.

19Daily Recordkeeping. On each day of operation, the Permittee shall calculate, record, and maintain a record ofthe combined fuel usage (bark, wood refuse, paper, and sludge). This is for the tons/hour fuel usage limit,calculated on a six-hour block average basis.

20 ESP Monitoring: The Permittee shall use the COMS (EQUI 80) to assess proper operation of the ESP (TREA5).


Title I Condition: 40 CFR52.21(j)(BACT) & Minn. R. 7007.3000,Title I Condition: 40 CFR pt. 52,21(k)(modeling) & Minn. R. 7007.3000



Minn. R. 7007.0800, subp. 5

Minn. R. 7017.2025, subp. 3

Minn. R. 7007.0800, subp. 5




19

Daily Recordkeeping. On each day of operation, the Permittee shall calculate, record, and maintain a record ofthe combined fuel usage (bark, wood refuse, paper, and sludge). This is for the tons/hour fuel usage limit,calculated on a six-hour block average basis.

20 ESP Monitoring: The Permittee shall use the COMS (EQUI 80) to assess proper operation of the ESP (TREA5).


22 The Permittee shall calibrate, maintain, and operate a continuous monitoring system for measuring andrecording Nitrogen Oxide, Sulfur Dioxide, and Carbon Monoxide emissions.

23 Emissions Monitoring: The owner or operator shall use a Carbon Monoxide CEMS to measure CarbonMonoxide emissions from EQUI 16 . Additional monitoring requirements are also located at EQUI 90.

24

Alternative Biomass Fuel Testing Authorization: The Permittee is authorized to conduct operational test burns ofthe following biomass fuels: BLS Soap, BLS Soap Tall Oil, Wastewater Treatment Residual, Glycerin orglycerol, herbs, nuts; vegetable oils; crop field residue or field processing residues; shells, husks, seeds, dust,screenings and other agricultural processing residues; cultivated grasses or grass by products and leaves.Acceptable biomass fuels do not include wood that has been painted or pressure treated; peat; off-sitegenerated waste oil, farm chemicals, pesticide containers, demolition waste except wood, waste from farms froman open dump, tire derived fuels, non-agricultural industrial process wastes except wood derived wastes or anymaterial meeting the definition of a hazardous waste.

25

Alternative Biomass Fuel Testing Requirements and Restrictions: Operational test burn will include, but not belimited to, nitrogen oxide, sulfur dioxide, carbon monoxide, and opacity emission limits monitored by existingCEMs and COMs. Alternative biomass fuels will further be limited to less than 5,000 tons and no more than 7days (or 168 hours) operation using the fuel, and a testing period to last no more than 30 operational daysbeginning the first day fuel is used. Further alternative test fuels will be limited to less than 25 percent of theheat input capacity of the boiler (i.e., less than 25% of 395 mmBTU/hr or 99 mmBTU/hr). Operational test burnswill be monitored for NOx, CO, SO2, and opacity. If operational test burns prove successful, then PM, PM-10and VOC performance test data will be gathered during the test. Preliminary fuel testing will be completed toestimate the maximum HAP emissions (HCl and Hg).

26Test burns shall consist of up to two phases - feasibility and performance testing. If an alternative biomass fuelmeets feasibility requirements (as defined by the Permittee) such that it may be proposed as an additional fuel,the Permittee may move into the performance testing phase.

27 Alternative Biomass Fuel Testing Restrictions: Feasibility test burns for any alternative biomass fuel shall belimited to no more than 168 hours of operation using the fuel, and a test period not to exceed 30 days.Performance tests for any alternative biomass fuel shall be limited to no more than 168 additional hours ofoperation using the proposed fuel and a test period not to exceed 60 additional days.

40 CFR 64.7(a), Minn. R. 7007.0800,subp. 2

40 CFR 63.7525(c), 40 CFR 64.7(a),Minn. R. 7017.1006, Title I Condition:40 CFR 52.21(j)(BACT) & Minn. R.7007.3000

40 CFR 64.7(a), Minn. R. 7017.1006,Title I Condition: 40 CFR52.21(j)(BACT) & Minn. R. 7007.3000

40 CFR 63.7525(a), Minn. R.7017.1006

Minn. R. 7007.0800, subp. 2

Minn. R. 7007.0800, subp. 2

Minn. R. 7007.0800, subp. 2




26

Test burns shall consist of up to two phases - feasibility and performance testing. If an alternative biomass fuelmeets feasibility requirements (as defined by the Permittee) such that it may be proposed as an additional fuel,the Permittee may move into the performance testing phase.

27

Alternative Biomass Fuel Testing Restrictions: Feasibility test burns for any alternative biomass fuel shall belimited to no more than 168 hours of operation using the fuel, and a test period not to exceed 30 days.Performance tests for any alternative biomass fuel shall be limited to no more than 168 additional hours ofoperation using the proposed fuel and a test period not to exceed 60 additional days.

28

The Permittee shall submit a performance test plan : Due 30 calendar days before Performance Test Date(Alternative Biomass Fuel Emission Testing submittal) of the operational and emission testing of a biomass fuel(emission testing will be conducted only if operational testing has been proven feasible), the permitee shallsubmit a written performance test notification and test plan. The test plan shall include (1) the type(s) andestimated amount of biomass to be tested, (2) operating parameters and anticipated fuel mixes during theemission testing of the boiler to be tested, (3) air pollutants that will be monitored (ie., PM, PM-10, and VOC),and (4) a testing schedule.

29

Alternative Biomass Fuel Emission Testing Notification and submittals;Pretest meeting: due 7 days before Performance TestTest Report: Due 45 days after Performance TestTest Report: CD copy due 105 days after Performance TestThe Notification, the test Plan, and Test Report may be submitted in alternative format as allowed by Minn. R.7017.2018.

30

NESHAP REQUIREMENTSThe affected source of 40 CFR pt. 63, subp. DDDDD is the collection at a major source of all existing industrial,commercial, and institutional boilers and process heaters within a subcategory as defined in 40 CFR Section63.7575. This unit is part of the subcategory "Stoker/sloped grate/other unit designed to burn wet biomass.".

31

Fuel Analysis. The Permittee must keep records of the type and amount of all fuels burned in each boiler orprocess heater during the reporting period to demonstrate that all fuel types and mixtures of fuels burned wouldresult in equal to or lower fuel input of chlorine, mercury, and TSM than the maximum values calculated duringthe last performance test, if you demonstrate compliance through performance testing.

32

To demonstrate continuous compliance with the CO emission limit, the Permittee must meet the requirementsbelow.

- Continuously monitor CO according to 40 CFR Sections 63.7525(a) and 63.7535.- Maintain a CO emission level below or at the CO emission limit at all times the affected unit is operating.- Keep records of CO levels according to 40 CFR Section 63.7555(b).- Record and make available upon request results of CO CEMS performance audits, dates and duration ofperiods when the CO CEMS is out of control to completion of the corrective actions necessary to return the COCEMS to operation consistent with the Site-Specific Monitoring Plan.

33The Permittee must be in compliance with the emission limits, work practice standards, and operating limits in40 CFR pt. 63, subp. DDDDD. These limits apply at all times the affected unit is operating, except during periodsof startup and shutdown.

34 Startup & Shutdown. For startup and shutdown, the Permittee must meet the work practice standards accordingto 40 CFR pt. 63, subp. DDDDD, Table 3, Items 5 and 6.

Minn. R. 7007.0800, subp. 2

Minn. R. 7017.2018, Minn. R.7017.2030, subps. 1-4


40 CFR 63.7490, Minn. R. 7011.7050

40 CFR 63.7540(a)(2), Minn. R.7011.7050

40 CFR 63.7540(a)(8), Minn. R.7011.7050

40 CFR 63.7505(a), Minn. R.7011.7050




33

The Permittee must be in compliance with the emission limits, work practice standards, and operating limits in40 CFR pt. 63, subp. DDDDD. These limits apply at all times the affected unit is operating, except during periodsof startup and shutdown.

34 Startup & Shutdown. For startup and shutdown, the Permittee must meet the work practice standards accordingto 40 CFR pt. 63, subp. DDDDD, Table 3, Items 5 and 6.

35 The Permittee must maintain records of the calendar date, time, occurrence and duration of each startup andshutdown.

36 The Permittee must maintain records of the type(s) and amount(s) of fuels used during each startup andshutdown.

37 Boiler Load. The Permittee must maintain the operating load of each unit such that it does not exceed 110percent of the highest hourly average operating load recorded during the most recent performance test.

38

The Permittee must demonstrate compliance with all applicable emission limits using performance stack testing,fuel analysis, or CMS, including a CEMS, COMS, CPMS, or PM CPMS, where applicable. The Permittee maydemonstrate compliance with the applicable emission limit for HCl, mercury, or TSM using fuel analysis if theemission rate calculated according to 40 CFR Section 63.7530(c) is less than the applicable emission limit. (Forgaseous fuels, the Permittee may not use fuel analyses to comply with the TSM alternative standard or the HClstandard.) Otherwise, the Permittee must demonstrate compliance for HCl, mercury, or TSM using performancetesting, if subject to an applicable emission limit listed in 40 CFR pt. 63, subp. DDDDD, Table 2.

39

Front-half Particulate Matter : The Permittee shall conduct performance test : Due 07/07/2019 every 36 months(rule states every third year). The performance test shall be conducted at worst case conditions as defined atMinn. R. 7017.2005, subp. 8, using EPA Reference Method 5.Annual performance tests must be completed no more than 13 months after the previous performance test,unless the performance test results are less than 75 percent of the limit for 2 consecutive years, then eachperformance test must be conducted no more than 37 months after the previous performance test.

40

Hydrochloric acid : The Permittee shall conduct performance test : Due 07/07/2019 every 36 months (rule statesevery third year). The performance test shall be conducted at worst case conditions as defined at Minn. R.7017.2005, subp. 8, using EPA Reference Method 26A. Annual performance tests must be completed no more than 13 months after the previous performance test,unless the performance test results are less than 75 percent of the limit for 2 consecutive years, then eachperformance test must be conducted no more than 37 months after the previous performance test.

41 Mercury : The Permittee shall conduct performance test : Due 07/07/2019 every 36 months (rules states everythird year). The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005,subp. 8, using EPA Reference Methods 29 or 30B. Annual performance tests must be completed no more than 13 months after the previous performance test,unless the performance test results are less than 75 percent of the limit for 2 consecutive years, then eachperformance test must be conducted no more than 37 months after the previous performance test.

40 CFR 63.7540(d), Minn. R.7011.7050

40 CFR 63.7555(i)

40 CFR 63.7555(j)


40 CFR 63.7505(c), Minn. R.7011.7050

40 CFR 63.7515(a), Minn. R.7011.7050

40 CFR 63.7515(a), Minn. R.7011.7050




40

Hydrochloric acid : The Permittee shall conduct performance test : Due 07/07/2019 every 36 months (rule statesevery third year). The performance test shall be conducted at worst case conditions as defined at Minn. R.7017.2005, subp. 8, using EPA Reference Method 26A. Annual performance tests must be completed no more than 13 months after the previous performance test,unless the performance test results are less than 75 percent of the limit for 2 consecutive years, then eachperformance test must be conducted no more than 37 months after the previous performance test.

41

Mercury : The Permittee shall conduct performance test : Due 07/07/2019 every 36 months (rules states everythird year). The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005,subp. 8, using EPA Reference Methods 29 or 30B. Annual performance tests must be completed no more than 13 months after the previous performance test,unless the performance test results are less than 75 percent of the limit for 2 consecutive years, then eachperformance test must be conducted no more than 37 months after the previous performance test.

42



43

PM < 10 micron : The Permittee shall conduct a performance test : Due before 08/08/2020 every 60 months tomeasure emissions. Testing is due by the end of each 60 month period following the initial performance testdate. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp.8, using EPA Reference Method 201A and 202, or other method approved by MPCA in the performance testplan approval.


44

Volatile Organic Compounds : The Permittee shall conduct a performance test : Due before 08/08/2020 every 60months to measure emissions. Testing is due by the end of each 60 month period following the initialperformance test date. The performance test shall be conducted at worst case conditions as defined at Minn. R.7017.2005, subp. 8, using EPA Reference Method 25A, or other method approved by MPCA in the performancetest plan approval.


45

The Permittee shall submit a compliance status report : Due by 31 days after end of each calendar half-yearaccording to 40 CFR Section 63.7550(h). The Compliance Status Reports must cover the applicable semiannualreporting period from January 1 through June 30 or the semiannual reporting period from July 1 throughDecember 31. The Compliance Status Report must be postmarked or submitted nolater than July 31 or January 31, whichever date is the first date following the end of the semiannual reportingperiod. The Compliance Status Report must contain the information specified in 40 CFR Section 63.7550(c).

46

The Permittee must comply with all applicable requirements of 40 CFR pt. 63, subp A, as follows:63.6(h)(2), 63.6(h)(4-9), 63.7(b), 63.7(c)(2-3), 63.7(d), 63.7(e)(2-3), 63.7(g), and 63.7(h). A copy of 40 CFR pt.63, subp. A is included in Appendix J.


EQUI 17(EU440)


3 The Permittee shall limit emissions of Nitrogen Oxides <= 0.20 pounds per million Btu heat input 30-day rollingaverage. This standard applies at all times including periods of startup, shutdown, or malfunction.

40 CFR 63.7515(a), Minn. R.7011.7050




40 CFR 63.7550(b)(3) & (4), 40 CFR pt.63, subp. DDDDD(Table 9), Minn. R.7011.7050

40 CFR 63.7565, 40 CFR pt. 63, subp.A, Minn. R. 7007.0400, subp. 3, Minn.R. 7007.1150-7007.1500, Minn. R.7011.7000





2The Permittee shall limit emissions of Nitrogen Oxides <= 0.050 pounds per million Btu heat input 30-day rollingaverage.

3 The Permittee shall limit emissions of Nitrogen Oxides <= 0.20 pounds per million Btu heat input 30-day rollingaverage. This standard applies at all times including periods of startup, shutdown, or malfunction.

4 The Permittee shall limit emissions of Carbon Monoxide <= 0.090 pounds per million Btu heat input 3-houraverage, as determined by performance test.


6The Permittee shall limit emissions of Volatile Organic Compounds <= 0.0090 pounds per million Btu heat input3-hour average, as determined by performance test, measured as Carbon excluding methane (this is equivalentto 3.4 lb/hr).

8 Fuel Burned: Fuel to be burned is limited to natural gas.

9

Annual Capacity Factor: The Permittee shall record and maintain records of the amount of fuel combusted eachday and calculate the annual capacity factor for natural gas for the reporting period. The annual capacity factoris determined on a 12-month rolling average basis with a new annual capacity factor calculated at the end ofeach calendar month.

10Annual Report: The Permittee shall submit an annual report : Due annually, by the 30th of January starting10/13/2010 . A report of the previous 12 monthly 12-month rolling average calculations for the annual capacityfactor shall be submitted.

16 The Permittee shall calibrate, maintain, and operate CEMS for measuring NOx and O2 (or CO2) emissionsdischarged to the atmosphere, and shall record the output of the system.

40 CFR 60.44b(a), Minn. R. 7011.0565





40 CFR 60.49b(d)(1), Minn. R.7011.0565

Minn. R. 7007.0800, subp. 2




10

Annual Report: The Permittee shall submit an annual report : Due annually, by the 30th of January starting10/13/2010 . A report of the previous 12 monthly 12-month rolling average calculations for the annual capacityfactor shall be submitted.

16 The Permittee shall calibrate, maintain, and operate CEMS for measuring NOx and O2 (or CO2) emissionsdischarged to the atmosphere, and shall record the output of the system.

17 The CEMS shall be operated and data recorded during all periods of operation of EQUI 17 except for CEMSbreakdowns and repairs. Data is recorded during calibration checks, and zero and span adjustments.

18The 1-hour average NOx emission rates measured by the NOx CEMS shall be expressed in lb/MMBtu heatinput and shall be used to calculate the 30-day average emission rate. The 1-hour averages shall be calculatedusing data points required under 40 CFR Section 60.13(h)(2).

19

When NOx emissions data are not obtained because of CEMS breakdowns, repairs, calibration checks, andzero and span adjustments, emission data will be obtained by using standby monitoring systems, Method 7 or7A of Appendix A of 40 CFR pt. 60, or other approved reference methods to provide emission data for aminimum of 75 percent of the operating hours of EQUI 17, in at least 22 out of 30 successive EQUI 17 operatingdays.

21The affected source of 40 CFR pt. 63, subp. DDDDD is the collection at a major source of all existing industrial,commercial, and institutional boilers and process heaters within a subcategory as defined in 40 CFR Section63.7575. This unit is part of the subcategory "units designed to burn gas 1 fuels".

3820



Carbon Monoxide : The Permittee shall conduct a performance test : Due before 08/08/2020 every 60 months tomeasure emissions. Testing is due by the end of each 60 month period following the initial performance testdate. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp.8, using EPA Reference Method 10,or other method approved by MPCA in the performance test plan approval.



40 CFR 60.48b(b)(1), Minn. R.7011.0565, Title I Condition: 40 CFR52.21(j)(BACT) & Minn. R. 7007.3000,Title I Condition: 40 CFR52.21(k)(modeling) & Minn. R.7007.3000

40 CFR 60.48b(c), Minn. R. 7011.0565

40 CFR 60.48b(d), Minn. R. 7011.0565

40 CFR 60.48b(f), Minn. R. 7011.0565

40 CFR 63.7490, Minn. R. 7011.7050





Subject ItemID Seq. # RequirementEQUI 17(EU440) 3820

Carbon Monoxide : The Permittee shall conduct a performance test : Due before 08/08/2020 every 60 months tomeasure emissions. Testing is due by the end of each 60 month period following the initial performance testdate. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp.8, using EPA Reference Method 10,or other method approved by MPCA in the performance test plan approval.


EQUI 18(EU460)



4 The Permittee shall limit emissions of Carbon Monoxide <= 0.090 pounds per million Btu heat input 3-houraverage, as determined by performance test.


6The Permittee shall limit emissions of Volatile Organic Compounds <= 0.0090 pounds per million Btu heat input3-hour average, as determined by performance test, measured as C excluding methane (this is equivalent to 3.4lb/hr).

8 Fuel Burned: Fuel to be burned is limited to natural gas.

9

Annual Capacity Factor: Record and maintain records of the amounts of each fuel combusted during each dayand calculate the annual capacity factor for natural gas each calendar quarter. The annual capacity factor isdetermined on a 12-month rolling average basis with a new annual capacity factor calculated at the end of eachcalendar month.

10 Annual Report: The Permittee shall submit an annual report : Due annually, by the 30th of January starting10/13/2010 . A report of the previous 12 monthly 12-month rolling average calculations for the annual capacityfactor shall be submitted.


40 CFR 60.44b(a), Minn. R. 7011.0565





40 CFR 60.49b(d), Minn. R. 7011.0565




9

Annual Capacity Factor: Record and maintain records of the amounts of each fuel combusted during each dayand calculate the annual capacity factor for natural gas each calendar quarter. The annual capacity factor isdetermined on a 12-month rolling average basis with a new annual capacity factor calculated at the end of eachcalendar month.

10Annual Report: The Permittee shall submit an annual report : Due annually, by the 30th of January starting10/13/2010 . A report of the previous 12 monthly 12-month rolling average calculations for the annual capacityfactor shall be submitted.

16 The Permittee shall calibrate, maintain, and operate a continuous monitoring system for measuring andrecording Nitrogen Oxide emissions.

17

Records of Startup, Shutdown, or Malfunction: Any owner or operator subject to the provisions of this part shallmaintain records of the occurrence and duration of any startup, shutdown, or malfunction in the operation of anaffected facility; any malfunction of the air pollution control equipment; or any periods during which a continuousmonitoring system or monitoring device is inoperative.

19The affected source of 40 CFR pt. 63, subp. DDDDD is the collection at a major source of all existing industrial,commercial, and institutional boilers and process heaters within a subcategory as defined in 40 CFR Section63.7575. This unit is part of the subcategory "units designed to burn gas 1 fuels".

3820

Carbon Monoxide : The Permittee shall conduct a performance test : Due before 08/08/2020 every 60 months tomeasure emissions. Testing is due by the end of each 60 month period following the initial performance testdate. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp.8, using EPA Reference Method 10, or other method approved by MPCA in the performance test plan approval.




EQUI 19(EU505)


3640 Opacity <= 20 percent opacity except for one six-minute per hour of not more than 60 percent opacity.

Minn. R. 7007.0800, subp. 2

40 CFR 60.45(a), Minn. R. 7017.1006,Title I Condition: 40 CFR52.21(j)(BACT) & Minn. R. 7007.3000,Title I Condition: 40 CFR pt. 52,21(k)(modeling) & Minn. R. 7007.3000

40 CFR 60.7(b), Minn. R. 7019.0100

40 CFR 63.7490, Minn. R. 7011.7050

Minn. R. 7017.2020, subp. 1, Title ICondition: 40 CFR 52.21(j)(BACT) &Minn. R. 7007.3000, Title I Condition:40 CFR 52.21(k)(modeling)


Minn. R. 7011.0710, subp. 1(A)




3Particulate Matter <= 0.30 grains per dry standard cubic foot of exhaust gas unless required to further reduceemissions to comply with the less stringent limit of either Minn. R. 7011.0730 or Minn. R. 7011.0735.


3650 Periodic Monitoring: the Permittee shall perform proper maintenance of the paper machines so as to preventexcessive amounts of particulate matter from being emitted from the associated stack/vents.

EQUI 20(EU520)




EQUI 21(EU530)


4 Opacity <= 20 percent opacity except for one six-minute period per hour of not more than 60 percent opacity.

3450 Fuel to be burned is limited to natural gas.

Minn. R. 7011.0710, subp. 1(B)

Minn. R. 7007.0800, subp. 4

Minn. R. 7011.0710, subp. 1(A)

Minn. R. 7011.0710, subp. 1(B)

Minn. R. 7007.0800, subp. 4

Minn. R. 7011.0610, subp. 1(A)(1)

Minn. R. 7011.0610, subp. 1(A)(2)




4 Opacity <= 20 percent opacity except for one six-minute period per hour of not more than 60 percent opacity.

3450 Fuel to be burned is limited to natural gas.


EQUI 22(EU540)




EQUI 24(EU903)



6 Operation and Maintenance Plan: The plan shall identify corrective action procedures to be followed to returnthe control equipment to within specified range(s); corrective action procedures to be followed in the event of amalfunction, breakdown or exceedance of operating ranges; a description of inspection procedures to befollowed; and records kept to demonstrate plan implementation.

Title I Condition: 40 CFR52.21(j)(BACT) & Minn. R. 7007.3000,Title I Condition: 40 CFR pt. 52,21(k)(modeling) & Minn. R. 7007.3000

Minn. R. 7007.0800, subp. 4

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

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

Minn. R. 7007.0800, subp. 4

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

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





6

Operation and Maintenance Plan: The plan shall identify corrective action procedures to be followed to returnthe control equipment to within specified range(s); corrective action procedures to be followed in the event of amalfunction, breakdown or exceedance of operating ranges; a description of inspection procedures to befollowed; and records kept to demonstrate plan implementation.

8 Control Equipment Monitoring: Observe and record once per operating day, the liquid flow rate and pressuredrop for TREA 25 and TREA 26.

9

The Permittee shall operate and maintain the control equipment (TREA 25 and TREA 26) at all times that stackgas from the control equipment is vented directly to the atmosphere. The Permittee shall document periods ofoperation of the control equipment and the periods that the bypass valve (213-ZS-062) directs stack gas fromthe control equipment to the atmosphere rather than directing the stack gas for combustion in Boliers #1 and #2(EQUIs 15 and 16).

11

TREA 25 (this requirement applies when the facility is not burning stack gas in Boilers #1 or #2): Liquid FlowRate >= 70 gallons per minute 3-hour block average. To calculate the average flow rate, divide total flow by totaloperating time in each three hour-block. Down time of 15 or more minutes is not to be included as operatingtime. Readings taken by continuous monitor at one minute increments.

12

TREA 25 (this requirement applies when the facility is not burning stack gas in Boilers #1 or #2): Pressure Drop>= 2.0 inches of water column 3-hour block average or as determined during the most recent performance test.Three-hour block average is the average scrubber pressure drop in each three-hour block. Downtime of 15 ormore minutes is not to be included as operating time.

3680

TREA 26 (this requirement applies when the facility is not burning stack gas in Boilers #1 or #2): Liquid FlowRate >= 788 gallons per minute 3-hour block average. To calculate the average flow rate, divide total flow bytotal operating time in each three hour-block. Down time of 15 or more minutes is not to be included asoperating time. Readings taken by continuous monitor at one minute increments.

3690


1 HAPs - Organic <= 20 percent of the mass of coating solids applied for each calendar month for the web coatingline (as defined in 40 CFR Section 63.3310).

Minn. R. 7007.0800, subp. 2

Minn. R. 7007.0800, subp. 14


Minn. R. 7017.2025, subp. 3

Minn. R. 7017.2025, subp. 3

Minn. R. 7017.2025, subp. 3

Minn. R. 7017.2025, subp. 3





EQUI 25(EU909)

1 HAPs - Organic <= 20 percent of the mass of coating solids applied for each calendar month for the web coatingline (as defined in 40 CFR Section 63.3310).

2

The Permittee shall maintain the following records on a monthly basis: Records specified in 40 CFR Section 63.10(b)(2) of all measurements need to demonstrate compliance,including: volatile matter and coating solids content data for the purpose of demonstrating compliance inaccordance with the requirements of 40 CFR Section 63.3360(d); material usage, organic HAP usage, volatilematter usage, and coating solids usage and compliance demonstrations using these data in accordance with 40CFR Section 63.3370(c).

3The monthly average of all coating materials used at an existing affected source does not exceed 0.2 kg organicHAP per kg coating solids as-applied on a monthly average basis using equation 5 of Section 63.3370 asspecified in the following requirements.

4The Permittee must determine the organic HAP applied on these web coating lines using Equation 5 ofAppendix C of this permit. The organic HAP emitted from an uncontrolled web coating line is equal to theorganic HAP applied on that web coating line.

5

By the end of each calendar month, the Permittee shall calculate the following for the previous calendar month: 1) The total organic HAP emitted by summing the HAP emissions calculated for all units subject to 40 CFR pt.63, subp. JJJJ as detailed earlier in this permit; 2) The coating solids content of each coating material applied during the month following the procedure detailedearlier in this permit; and 3) The total organic HAP emission rate based on coating solids applied using Equation 5 of Appendix C of thispermit.

6

Compliance Status Report: The Permittee shall submit a compliance status report : Due semiannually, by the30th of January and July starting 10/13/2010, including, at a minimum, the following information:1) Company name and address; 2) A statement by a responsible official with that official's name, title, andsignature certifying the accuracy of the content of the report; 3) Date of report and beginning and ending datesof the reporting period; 4) If there are no deviations from any emission limitations (emission limit or operatinglimit) that apply to you, a statement that there were no deviations from the emission limitations during thereporting period, and that no CMS was inoperative, inactive, malfunctioning, out-of-control, repaired, or adjusted;and 5) For each deviation from an emission limitation (emission limit or operating limit) that applies to you, theinformation listed in 40 CFR Section 63.3400(c)(2)(v)(A)-(C).

7

The Permittee must comply with all applicable requirements of 40 CFR pt. 63, subp A, as follows:63.4(b), 63.5(b)(4), 63.5(b)(6), 63.6(e)(1)(i-ii), 63.6(f)(2-3), 63.9(h), 63.9(j), 63.10(a), 63.10(b)(1), 63.10(d)(1),and 63.10(d)(4). A copy of 40 CFR pt. 63, subp. A is included in Appendix J.


2 Relative Accuracy Test Audit (RATA) Results Summary: due 30 days after end of each calendar quarter inwhich a RATA was conducted.

40 CFR 63.3320(b)(3), Minn. R.7011.7385

40 CFR 63.10(b)(1), 40 CFR63.3410(a), Minn. R. 7011.7385

40 CFR 63.3370(a)(2)(iv), 40 CFR63.3370(c)(5)(ii), Minn. R. 7011.7385

40 CFR 63.3370(c)(4), Minn. R.7011.7385

40 CFR 63.3370(c)(4), Minn. R.7011.7385

40 CFR 63.3400(c), Minn. R.7011.7385

40 CFR pt. 63, subp. A, 40 CFR pt. 63,subp. JJJJ, Minn. R. 7007.0400, subp.3, Minn. R. 7007.1150-7007.1500,Minn. R. 7011.7000




The Permittee must comply with all applicable requirements of 40 CFR pt. 63, subp A, as follows:63.4(b), 63.5(b)(4), 63.5(b)(6), 63.6(e)(1)(i-ii), 63.6(f)(2-3), 63.9(h), 63.9(j), 63.10(a), 63.10(b)(1), 63.10(d)(1),and 63.10(d)(4). A copy of 40 CFR pt. 63, subp. A is included in Appendix J.


EQUI 78(MR916)


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

5

The Permittee shall conduct CEMS cylinder gas audit (CGA) : Due semiannually (end of every second QAoperating quarter in which there are at least 168 unit operating hours) except that a CGA is not required duringany quarter in which a RATA was performed. The initial CGA must be performed within 180 days followingcertification of the CEMS. The CGAs shall be conducted according to the procedures outlined in Minn. R.7017.1170, subp 4a(A). If the monitored emission unit is not in operation on the CGA due date, the owner oroperator has a grace period of 168 operating hours to perform the CGA.

6

The Permittee shall conduct a relative accuracy test audit : Due annually (end of every fourth QA operatingquarter). RATAs shall be conducted and frequency may be reduced according to the procedures outlined inMinn. R. 7017.1170, subp. 5a. If the monitored emission unit is not in operation on the RATA due date, theowner or operator has a grace period of 720 operating hours to perform the RATA.

7 Sulfur - Total Reduced including H2S: Emissions Monitoring: The owner or operator shall use a CEMS tomeasure emissions from EQUI 13.

8

Certification Test Plan due 30 days before Certification Test.Certification Test Pretest Meeting due 7 days before Certification Test.Certification Test Report due 45 days after Certification Test.

The Test Plan and Test Report must be submitted in a format specified by the commissioner.

9

Continuous Operation: CEMS must be operated and data recorded during all periods of emission unit operationincluding periods of emission unit start-up, shutdown, or malfunction except for periods of acceptable monitordowntime. This requirement applies whether or not a numerical emission limit applies during these periods. ACEMS must not be bypassed except in emergencies where failure to bypass would endanger human health,safety, or plant equipment.

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

Minn. R. 7017.1180, subp. 3

Minn. R. 7017.1180, subp. 1

Minn. R. 7017.1170, subp. 4a

Minn. R. 7017.1170, subp. 5a

Minn. R. 7017.1006

Minn. R. 7017.1060, subp. 1-3, Minn.R. 7017.1080

Minn. R. 7017.1090



Subject ItemID Seq. # RequirementEQUI 78(MR916)

9


10

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

11

QA Plan: Develop and implement a written quality assurance plan that covers each CEMS. The plan shall be onsite and available for inspection within 30 days after monitor certification. The plan shall include themanufacturer's spare parts list for each CEMS and require that those parts be kept at the facility unless theCommissioner gives written approval to exclude specific spare parts from the list.

12

CEMS Daily Calibration Drift (CD) Test: The CD shall be quantified and recorded at zero (low-level) and upscale(high-level) gas concentrations at least once daily according to the procedures listed in Minn. R. 7017.1170,subp. 3(A) and (B), 40 CFR Section 60.13(d)(1) or 40 CFR pt. 75, Appendix B as applicable for each pollutantconcentration, each diluent monitor, and for each monitor range. If no span value is specified in the applicablerequirement or in a compliance document, the Permittee shall use a span value equivalent to 1.5 times theemission limit.

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

14CEMS Certification/Recertification Test: due 90 days after the first excess emissions report required for theCEMS or any change which invalidates the monitor's certification status as outlined in Minn. R. 7017.1050, subp.2.

15Recordkeeping: The owner or operator must retain records of all CEMS monitoring data and support informationfor a period of five years from the date of the monitoring sample, measurement or report. Records shall be keptat the source.

EQUI 79(MR320)

1

Continuous operation. COMS must be operated and data recorded during all periods of unit operation includingperiods of unit start-up, shutdown, or malfunction except for periods of acceptable monitor downtime. Thisrequirement to operate the monitor applies whether or not a numerical emission limit applies during theseperiods. A COMS must not be bypassed except in emergencies where failure to bypass the COMS wouldendanger human health, safety, or plant equipment. Acceptable monitor downtime includes reasonable periodsas listed in Items A, B, C and D of Minn. R. 7017.1090.

2 Emissions Monitoring: The owner or operator shall use a COMS to measure Opacity from EQUI 9.

Minn. R. 7017.1160, subp. 1-2

Minn. R. 7017.1170, subp. 2

Minn. R. 7017.1170, subp. 3

Minn. R. 7017.1180, subp. 2

Minn. R. 7017.1050, subp. 1

Minn. R. 7017.1130

Minn. R. 7017.1090




1


2 Emissions Monitoring: The owner or operator shall use a COMS to measure Opacity from EQUI 9.

3Monitoring Data: All COMS data must be reduced to six-minute averages. A six minute average is valid only if itcontains data from at least five minutes within the averaging period. COMS data shall be reduced and calculatedas outlined in Minn. R. 7017.1200, subp. 3.

5

The Permittee shall conduct COMS calibration error audit : Due quarterly according to Procedure 3 of 40 CFRPt. 60, Appendix F. Quarterly performance audits will include: optical alignment, calibration error, and zerocompensation. Sources that achieve quality assured data for four consecutive quarters may reduce auditfrequency to semi-annually. If an audit is failed, the source must resume quarterly audits to demonstrateperformance again for four consecutive quarters.

6 The Permittee shall perform zero alignment as described in Procedure 3, section 10.3 of 40 CFR Pt. 60,Appendix F.

7 COMS Daily Calibration Drift Test: The owner or operator of a COMS shall conduct daily instrument zero andupscale drift checks according to Procedure 3, section 10.1 of 40 CFR Pt. 60, Appendix F.

9 COMS Calibration Error Audit Results Summary: due 30 days after end of each calendar quarter in which theCOMS calibration error audit was completed.

11COMS Certification/Recertification Test: due 90 days after the first excess emissions report required for theCOMS or any change which invalidates the monitor's certification status as outlined in Minn. R. 7017.1050,subp. 2.

12 Recordkeeping: The owner or operator must retain records of all COMS monitoring data and support informationfor a period of five years from the date of the monitoring sample, measurement or report. Records shall be keptat the source.

Minn. R. 7017.1006

Minn. R. 7017.1200, subp. 1-3

Minn. R. 7017.1215

Minn. R. 7017.1215

Minn. R. 7017.1215

Minn. R. 7017.1220

Minn. R. 7017.1050, subp. 1




11

COMS Certification/Recertification Test: due 90 days after the first excess emissions report required for theCOMS or any change which invalidates the monitor's certification status as outlined in Minn. R. 7017.1050,subp. 2.

12Recordkeeping: The owner or operator must retain records of all COMS monitoring data and support informationfor a period of five years from the date of the monitoring sample, measurement or report. Records shall be keptat the source.

14QA Plan: the facility owner or operator must conduct quality assurance and quality control as specified inProcedure 3 - Quality Assurance Requirements for Continuous Opacity Monitoring Systems at StationarySources, 40 CFR Pt. 60, Appendix F.

EQUI 80(MR432)

1 Emissions Monitoring: The owner or operator shall use a COMS to measure Opacity from EQUI 16. Additionalmonitoring requirements are also located at EQUI 16.

2


3Monitoring Data: All COMS data must be reduced to six-minute averages. A six minute average is valid only if itcontains data from at least five minutes within the averaging period. COMS data shall be reduced and calculatedas outlined in Minn. R. 7017.1200, subp. 3.

5

The Permittee shall conduct COMS calibration error audit : Due quarterly according to Procedure 3 of 40 CFRPt. 60, Appendix F. Quarterly performance audits will include: optical alignment, calibration error, and zerocompensation. Sources that achieve quality assured data for four consecutive quarters may reduce auditfrequency to semi-annually. If an audit is failed, the source must resume quarterly audits to demonstrateperformance again for four consecutive quarters.

6 The Permittee shall perform zero alignment as described in Procedure 3, section 10.3 of 40 CFR Pt. 60,Appendix F.


Minn. R. 7017.1130

Minn. R. 7017.1215

Minn. R. 7017.1006

Minn. R. 7017.1090

Minn. R. 7017.1200, subp. 1-3

Minn. R. 7017.1215

Minn. R. 7017.1215




6The Permittee shall perform zero alignment as described in Procedure 3, section 10.3 of 40 CFR Pt. 60,Appendix F.


9 COMS Calibration Error Audit Results Summary: due 30 days after end of each calendar quarter in which theCOMS calibration error audit was completed.

11COMS Certification/Recertification Test: due 90 days after the first excess emissions report required for theCOMS or any change which invalidates the monitor's certification status as outlined in Minn. R. 7017.1050,subp. 2.

12Recordkeeping: The owner or operator must retain records of all COMS monitoring data and support informationfor a period of five years from the date of the monitoring sample, measurement or report. Records shall be keptat the source.

14QA Plan: the facility owner or operator must conduct quality assurance and quality control as specified inProcedure 3 - Quality Assurance Requirements for Continuous Opacity Monitoring Systems at StationarySources, 40 CFR Pt. 60, Appendix F.

EQUI 86(MR911)



5 The Permittee shall conduct CEMS cylinder gas audit (CGA) : Due semiannually (end of every second QAoperating quarter in which there are at least 168 unit operating hours) except that a CGA is not required duringany quarter in which a RATA was performed. The initial CGA must be performed within 180 days followingcertification of the CEMS. The CGAs shall be conducted according to the procedures outlined in Minn. R.7017.1170, subp 4a(A). If the monitored emission unit is not in operation on the CGA due date, the owner oroperator has a grace period of 168 operating hours to perform the CGA.

Minn. R. 7017.1215

Minn. R. 7017.1220

Minn. R. 7017.1050, subp. 1

Minn. R. 7017.1130

Minn. R. 7017.1215

Minn. R. 7017.1180, subp. 3

Minn. R. 7017.1180, subp. 1




4Cylinder Gas Audit (CGA) Results Summary: due 30 days after end of each calendar quarter in which a CGAwas conducted.

5


6


7 Nitrogen Oxides: Emissions Monitoring: The owner or operator shall use a CEMS to measure emissions fromEQUI 9.

8



9


10


11


12 CEMS Daily Calibration Drift (CD) Test: The CD shall be quantified and recorded at zero (low-level) and upscale(high-level) gas concentrations at least once daily according to the procedures listed in Minn. R. 7017.1170,subp. 3(A) and (B), 40 CFR Section 60.13(d)(1) or 40 CFR pt. 75, Appendix B as applicable for each pollutantconcentration, each diluent monitor, and for each monitor range. If no span value is specified in the applicablerequirement or in a compliance document, the Permittee shall use a span value equivalent to 1.5 times theemission limit.

Minn. R. 7017.1170, subp. 4a

Minn. R. 7017.1170, subp. 5a

Minn. R. 7017.1006

Minn. R. 7017.1060, subp. 1-3, Minn.R. 7017.1080

Minn. R. 7017.1090

Minn. R. 7017.1160, subp. 1-2

Minn. R. 7017.1170, subp. 2




11


12





EQUI 87(MR912)



6


7 The Permittee shall conduct a relative accuracy test audit : Due annually (end of every fourth QA operatingquarter). RATAs shall be conducted and frequency may be reduced according to the procedures outlined inMinn. R. 7017.1170, subp. 5a. If the monitored emission unit is not in operation on the RATA due date, theowner or operator has a grace period of 720 operating hours to perform the RATA.

Minn. R. 7017.1170, subp. 3

Minn. R. 7017.1180, subp. 2

Minn. R. 7017.1050, subp. 1

Minn. R. 7017.1130

Minn. R. 7017.1180, subp. 3

Minn. R. 7017.1180, subp. 1

Minn. R. 7017.1170, subp. 4a




6


7


8 Sulfur - Total Reduced including H2S: Emissions Monitoring: The owner or operator shall use a CEMS tomeasure emissions from EQUI 9.

9



10


11


12


13



Minn. R. 7017.1170, subp. 5a

Minn. R. 7017.1006

Minn. R. 7017.1060, subp. 1-3, Minn.R. 7017.1080

Minn. R. 7017.1090

Minn. R. 7017.1160, subp. 1-2

Minn. R. 7017.1170, subp. 2

Minn. R. 7017.1170, subp. 3




13





EQUI 88(MR913)



5


6


7 Carbon Monoxide: Emissions Monitoring: The owner or operator shall use a CEMS to measure emissions fromEQUI 9.

Minn. R. 7017.1180, subp. 2

Minn. R. 7017.1050, subp. 1

Minn. R. 7017.1130

Minn. R. 7017.1180, subp. 3

Minn. R. 7017.1180, subp. 1

Minn. R. 7017.1170, subp. 4a

Minn. R. 7017.1170, subp. 5a




6



8



9


10


11


12



14 CEMS Certification/Recertification Test: due 90 days after the first excess emissions report required for theCEMS or any change which invalidates the monitor's certification status as outlined in Minn. R. 7017.1050, subp.2.

Minn. R. 7017.1006

Minn. R. 7017.1060, subp. 1-3, Minn.R. 7017.1080

Minn. R. 7017.1090

Minn. R. 7017.1160, subp. 1-2

Minn. R. 7017.1170, subp. 2

Minn. R. 7017.1170, subp. 3

Minn. R. 7017.1180, subp. 2




13Relative Accuracy Test Audit (RATA) Notification: due 30 days before CEMS Relative Accuracy Test Audit(RATA).



EQUI 90(MR915)



5The Permittee shall conduct CEMS cylinder gas audit (CGA) : Due by the end of each three of four calendarquarters but no more than three quarters in succession. A CGA is not required during any calendar quarter inwhich a RATA was performed.

6 The Permittee shall conduct a relative accuracy test audit : Due one of each four calendar quarters.


8 Certification Test Plan due 30 days before Certification Test.Certification Test Pretest Meeting due 7 days before Certification Test.Certification Test Report due 45 days after Certification Test.


Minn. R. 7017.1050, subp. 1

Minn. R. 7017.1130

Minn. R. 7017.1180, subp. 3

Minn. R. 7017.1180, subp. 1

40 CFR 63.7525(a), Minn. R.7017.1170, subp. 4a

40 CFR 63.7525(a), Minn. R.7017.1170, subp. 5a

Minn. R. 7017.1006




7Carbon Monoxide: Emissions Monitoring: The owner or operator shall use a CEMS to measure emissions fromEQUI 16.

8



9


10


11


12


13

Relative Accuracy Test Audit (RATA) Notification: due 60 days before CEMS Relative Accuracy Test Audit(RATA). This is the notification required by 40 CFR pt. 63, subp DDDDD.

Minn. R. 7017.1170, subp. 2 requires a notification of 30 days.


15 Recordkeeping: The owner or operator must retain records of all CEMS monitoring data and support informationfor a period of five years from the date of the monitoring sample, measurement or report. Records shall be keptat the source.

Minn. R. 7017.1060, subp. 1-3, Minn.R. 7017.1080

Minn. R. 7017.1090

Minn. R. 7017.1160, subp. 1-2

Minn. R. 7017.1170, subp. 2

Minn. R. 7017.1170, subp. 3

40 CFR 63.7575(2)(i), 40 CFR63.8(e)(2)

Minn. R. 7017.1050, subp. 1




14

CEMS Certification/Recertification Test: due 90 days after the first excess emissions report required for theCEMS or any change which invalidates the monitor's certification status as outlined in Minn. R. 7017.1050, subp.2.


EQUI 109(MR421)



4


5


6 Oxygen: Emissions Monitoring: The owner or operator shall use a CEMS to measure emissions from EQUI 15.

7



8 Continuous Operation: CEMS must be operated and data recorded during all periods of emission unit operationincluding periods of emission unit start-up, shutdown, or malfunction except for periods of acceptable monitordowntime. This requirement applies whether or not a numerical emission limit applies during these periods. ACEMS must not be bypassed except in emergencies where failure to bypass would endanger human health,safety, or plant equipment.

Minn. R. 7017.1130

Minn. R. 7017.1180, subp. 3

Minn. R. 7017.1180, subp. 1

Minn. R. 7017.1170, subp. 4a

Minn. R. 7017.1170, subp. 5a

Minn. R. 7017.1006

Minn. R. 7017.1060, subp. 1-3, Minn.R. 7017.1080




7



8


9


10


11






Minn. R. 7017.1090

Minn. R. 7017.1160, subp. 1-2

Minn. R. 7017.1170, subp. 2

Minn. R. 7017.1170, subp. 3

Minn. R. 7017.1180, subp. 2

Minn. R. 7017.1050, subp. 1

Minn. R. 7017.1130



Subject ItemID Seq. # RequirementEQUI 109(MR421) 14

Recordkeeping: The owner or operator must retain records of all CEMS monitoring data and support informationfor a period of five years from the date of the monitoring sample, measurement or report. Records shall be keptat the source.

EQUI 110(MR420)



5


6



8



9



Minn. R. 7017.1180, subp. 3

Minn. R. 7017.1180, subp. 1

Minn. R. 7017.1170, subp. 4a

Minn. R. 7017.1170, subp. 5a

Minn. R. 7017.1006

Minn. R. 7017.1060, subp. 1-3, Minn.R. 7017.1080

Minn. R. 7017.1090




9


10


11


12





EQUI 111(MR441)



Minn. R. 7017.1160, subp. 1-2

Minn. R. 7017.1170, subp. 2

Minn. R. 7017.1170, subp. 3

Minn. R. 7017.1180, subp. 2

Minn. R. 7017.1050, subp. 1

Minn. R. 7017.1130

Minn. R. 7017.1180, subp. 3




3Relative Accuracy Test Audit (RATA) Results Summary: due 30 days after end of each calendar quarter inwhich a RATA was conducted.




9



10


11

QA Plan: Develop and implement a written quality assurance plan that covers each CEMS. The plan shall be onsite and available for inspection within 30 days after monitor certification. The plan shall contain all of theinformation required by 40 CFR Part 60, Appendix F, Section 3. The plan shall include the manufacturer's spareparts list for each CEMS and require that those parts be kept at the facility unless the Commissioner giveswritten approval to exclude specific spare parts from the list.

12

CEMS QA/QC: The owner or operator of an affected facility is subject to the performance specifications listed in40 CFR pt. 60, Appendix B and shall operate, calibrate, and maintain each CEMS according to the QA/QCprocedures in 40 CFR pt. 60, Appendix F as amended and maintain a written QA/QC program available in aform suitable for inspection.

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

Minn. R. 7017.1180, subp. 1

40 CFR pt. 60, subp. Db, Minn. R.7017.1010, subp 1

40 CFR 60.13(b), Minn. R. 7017.1050,subp. 1

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

40 CFR 60.13(e), Minn. R. 7017.1090

40 CFR pt. 60, Appendix F, 3, Minn. R.7017.1170, subp. 2

40 CFR 60.13(a), 40 CFR pt. 60,Appendix F




12


13

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


15 CEMS Monitor Design: Each CEMS shall be designed to complete a minimum of one cycle of sampling,analyzing, and data recording in each 15-minute period.

16The Permittee shall conduct a cylinder gas audit : Due by the end of each three of four calendar quarters but nomore than three quarters in succession. A CGA is not required during any calendar quarter in which a RATAwas performed.


EQUI 124(MR325)




40 CFR 60.13(d)(1), 40 CFR pt. 60,Appendix F, 4.1, Minn. R. 7017.1170,subp. 3

40 CFR 60.7(f), Minn. R. 7017.1130

40 CFR 60.13(e)(2)

40 CFR pt. 60, Appendix F, 5.1.2, Minn.R. 7017.1170, subp. 4

40 CFR pt. 60, Appendix F, 5.1.1

Minn. R. 7017.1180, subp. 3

Minn. R. 7017.1180, subp. 1





4


5



7



8


9


10



Minn. R. 7017.1170, subp. 4a

Minn. R. 7017.1170, subp. 5a

Minn. R. 7017.1006

Minn. R. 7017.1060, subp. 1-3, Minn.R. 7017.1080

Minn. R. 7017.1090

Minn. R. 7017.1160, subp. 1-2

Minn. R. 7017.1170, subp. 2




10


11





EQUI 125(MR327)



5


6 The Permittee shall conduct a relative accuracy test audit : Due annually (end of every fourth QA operatingquarter). RATAs shall be conducted and frequency may be reduced according to the procedures outlined inMinn. R. 7017.1170, subp. 5a. If the monitored emission unit is not in operation on the RATA due date, theowner or operator has a grace period of 720 operating hours to perform the RATA.

Minn. R. 7017.1170, subp. 3

Minn. R. 7017.1180, subp. 2

Minn. R. 7017.1050, subp. 1

Minn. R. 7017.1130

Minn. R. 7017.1180, subp. 3

Minn. R. 7017.1180, subp. 1

Minn. R. 7017.1170, subp. 4a




5


6



8



9


10


11


12



Minn. R. 7017.1170, subp. 5a

Minn. R. 7017.1006

Minn. R. 7017.1060, subp. 1-3, Minn.R. 7017.1080

Minn. R. 7017.1090

Minn. R. 7017.1160, subp. 1-2

Minn. R. 7017.1170, subp. 2

Minn. R. 7017.1170, subp. 3




12





EQUI 128(MR440)







Minn. R. 7017.1180, subp. 2

Minn. R. 7017.1050, subp. 1

Minn. R. 7017.1130

Minn. R. 7017.1180, subp. 3

Minn. R. 7017.1180, subp. 1

40 CFR pt. 60, subp. Db, Minn. R.7017.1010, subp 1

40 CFR 60.13(b), Minn. R. 7017.1050,subp. 1




8


9



10


11

QA Plan: Develop and implement a written quality assurance plan that covers each CEMS. The plan shall be onsite and available for inspection within 30 days after monitor certification. The plan shall contain all of theinformation required by 40 CFR Part 60, Appendix F, Section 3. The plan shall include the manufacturer's spareparts list for each CEMS and require that those parts be kept at the facility unless the Commissioner giveswritten approval to exclude specific spare parts from the list.

12


13

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


15 CEMS Monitor Design: Each CEMS shall be designed to complete a minimum of one cycle of sampling,analyzing, and data recording in each 15-minute period.

16 The Permittee shall conduct a cylinder gas audit : Due by the end of each three of four calendar quarters but nomore than three quarters in succession. A CGA is not required during any calendar quarter in which a RATAwas performed.

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

40 CFR 60.13(e), Minn. R. 7017.1090

40 CFR pt. 60, Appendix F, 3, Minn. R.7017.1170, subp. 2

40 CFR 60.13(a), 40 CFR pt. 60,Appendix F

40 CFR 60.13(d)(1), 40 CFR pt. 60,Appendix F, 4.1, Minn. R. 7017.1170,subp. 3

40 CFR 60.7(f), Minn. R. 7017.1130

40 CFR 60.13(e)(2)




15CEMS Monitor Design: Each CEMS shall be designed to complete a minimum of one cycle of sampling,analyzing, and data recording in each 15-minute period.

16The Permittee shall conduct a cylinder gas audit : Due by the end of each three of four calendar quarters but nomore than three quarters in succession. A CGA is not required during any calendar quarter in which a RATAwas performed.


EQUI 130(MR431)



4The Permittee shall conduct CEMS cylinder gas audit (CGA) : Due by the end of each three of four calendarquarters but no more than three quarters in succession. A CGA is not required during any calendar quarter inwhich a RATA was performed.





40 CFR pt. 60, Appendix F, 5.1.2, Minn.R. 7017.1170, subp. 4

40 CFR pt. 60, Appendix F, 5.1.1

Minn. R. 7017.1180, subp. 3

Minn. R. 7017.1180, subp. 1

40 CFR 63.7525(a), Minn. R.7017.1170, subp. 4a

40 CFR 63.7525(a), Minn. R.7017.1170, subp. 5a

Minn. R. 7017.1006





7



8


9


10


11




14 Recordkeeping: The owner or operator must retain records of all CEMS monitoring data and support informationfor a period of five years from the date of the monitoring sample, measurement or report. Records shall be keptat the source.

Minn. R. 7017.1060, subp. 1-3, Minn.R. 7017.1080

Minn. R. 7017.1090

Minn. R. 7017.1160, subp. 1-2

Minn. R. 7017.1170, subp. 2

Minn. R. 7017.1170, subp. 3

Minn. R. 7017.1180, subp. 2

Minn. R. 7017.1050, subp. 1




13



EQUI 135(MR461)



4


5



7



8 Continuous Operation: CEMS must be operated and data recorded during all periods of emission unit operationincluding periods of emission unit start-up, shutdown, or malfunction except for periods of acceptable monitordowntime. This requirement applies whether or not a numerical emission limit applies during these periods. ACEMS must not be bypassed except in emergencies where failure to bypass would endanger human health,safety, or plant equipment.

Minn. R. 7017.1130

Minn. R. 7017.1180, subp. 3

Minn. R. 7017.1180, subp. 1

Minn. R. 7017.1170, subp. 4a

Minn. R. 7017.1170, subp. 5a

Minn. R. 7017.1006

Minn. R. 7017.1060, subp. 1-3, Minn.R. 7017.1080




7



8


9


10


11






Minn. R. 7017.1090

Minn. R. 7017.1160, subp. 1-2

Minn. R. 7017.1170, subp. 2

Minn. R. 7017.1170, subp. 3

Minn. R. 7017.1180, subp. 2

Minn. R. 7017.1050, subp. 1

Minn. R. 7017.1130



Subject ItemID Seq. # RequirementEQUI 135(MR461) 14

Recordkeeping: The owner or operator must retain records of all CEMS monitoring data and support informationfor a period of five years from the date of the monitoring sample, measurement or report. Records shall be keptat the source.

EQUI 136(MR460)



5


6



8



9



Minn. R. 7017.1180, subp. 3

Minn. R. 7017.1180, subp. 1

Minn. R. 7017.1170, subp. 4a

Minn. R. 7017.1170, subp. 5a

Minn. R. 7017.1006

Minn. R. 7017.1060, subp. 1-3, Minn.R. 7017.1080

Minn. R. 7017.1090




9


10


11


12





EQUI 940(EU917)

1 Particulate Matter <= 3.0 pounds per hour 3-hour average, as determined by performance test.

2 PM < 10 micron <= 2.9 pounds per hour 3-hour average, as determined by performance test.

Minn. R. 7017.1160, subp. 1-2

Minn. R. 7017.1170, subp. 2

Minn. R. 7017.1170, subp. 3

Minn. R. 7017.1180, subp. 2

Minn. R. 7017.1050, subp. 1

Minn. R. 7017.1130





1 Particulate Matter <= 3.0 pounds per hour 3-hour average, as determined by performance test.

2 PM < 10 micron <= 2.9 pounds per hour 3-hour average, as determined by performance test.

3 Periodic Monitoring: the Permittee shall perform proper maintenance of the cyclone so as to prevent excessiveamounts of particulate matter from being emitted from STRU 82.

5

PM < 10 micron : The Permittee shall conduct an initial performance test : Due 2556 calendar days after PermitIssuance Date to measure emissions. The performance test shall be conducted at worst case conditions asdefined at Minn. R. 7017.2025, subp. 2, using EPA Reference Method 201A, or other method approved byMPCA in the performance test plan approval.

6

Particulate Matter : The Permittee shall conduct an initial performance test : Due 2556 calendar days afterPermit Issuance Date to measure emissions. The performance test shall be conducted at worst case conditionsas defined at Minn. R. 7017.2025, subp. 2, using EPA Reference Methods 5 and 202, or other method approvedby MPCA in the performance test plan approval.

7

PM < 10 micron: The Permittee shall submit a test frequency plan : Due 60 calendar days after InitialPerformance Test Date for PM < 10 emissions. The plan shall specify a testing frequency based on the test dataand MPCA guidance. Future performance tests based on 12-month, 36-month, or 60-month intervals, or asapplicable, shall be required upon written approval of the MPCA.

8

Particulate Matter: The Permittee shall submit a test frequency plan : Due 60 calendar days after InitialPerformance Test Date for PM emissions. The plan shall specify a testing frequency based on the test data andMPCA guidance. Future performance tests based on 12-month, 36-month, or 60-month intervals, or asapplicable, shall be required upon written approval of the MPCA.

EQUI 944(EU602)

1 Wastewater: Process Throughput <= 1700 million gallons per year 12-month rolling sum.

2 Monthly Recordkeeping -- wastewater process rate

By the 15th of the month, the Permittee shall calculate and record the following: 1) The amount of wastewater processed for the previous calendar month 2) The 12-month rolling sum of the amount of wastewater processed for the previous 12-month period bysumming the monthly emissions data for the previous 12 months.


Minn. R. 7007.0800, subp. 4









1 Wastewater: Process Throughput <= 1700 million gallons per year 12-month rolling sum.

2

Monthly Recordkeeping -- wastewater process rate

By the 15th of the month, the Permittee shall calculate and record the following: 1) The amount of wastewater processed for the previous calendar month 2) The 12-month rolling sum of the amount of wastewater processed for the previous 12-month period bysumming the monthly emissions data for the previous 12 months.

3 Reporting: The Permittee shall submit an annual report : Due annually, by the 30th of January for the previous12 monthly 12-month rolling sum calculations of wastewater throughput.

EQUI 945(EU322)

1The Permittee shall limit emissions of Particulate Matter <= 7.3 pounds per hour 3-hour average, as determinedby performance test. This is based on an EPA approved limit from a letter dated September 29, 2008 (and theTotal Facility BLS limit at that time).

2 The Permittee shall limit emissions of Particulate Matter <= 0.20 pounds per ton of BLS (black liquor solids).This is the 40 CFR pt. 60, subp. BB and 40 CFR pt. 63, subp. MM limit.

3The Permittee shall limit emissions of PM < 10 micron <= 7.3 pounds per hour 3-hour average, as determined byperformance test. This is based on an EPA approved limit from a letter dated September 29, 2008 (and the TotalFacility BLS limit at that time).

4 The Permittee shall limit Opacity <= 20 percent opacity 6-minute average.

5 The Permittee shall limit emissions of Nitrogen Oxides <= 0.033 pounds per ton of BLS (black liquor solids)produced.

6 The Permittee shall limit emissions of Sulfur Dioxide <= 4.3 pounds per hour 3-hour average, as determined byperformance test. (this is equivalent to 0.090 lb/ton BLS).


Minn. R. 7007.0800, supb. 6

40 CFR 63.862(a)(1)(i)(B), Title ICondition: 40 CFR52.21(b)(2)(i)(netting) & Minn. R.7007.3000, Title I Condition: 40 CFR52.21(k)(modeling) & Minn. R.7007.3000

40 CFR 60.282(a)(2) & (4), 40 CFR63.862(a)(1)(i)(B), Minn. R. 7011.2450,Minn. R. 7011.7700

40 CFR 63.862(a)(1)(i)(B), Title ICondition: 40 CFR52.21(b)(2)(i)(netting) & Minn. R.7007.3000, Title I Condition: 40 CFR52.21(k)(modeling) & Minn. R.7007.3000

Minn. R. 7007.0800, subp. 2





5The Permittee shall limit emissions of Nitrogen Oxides <= 0.033 pounds per ton of BLS (black liquor solids)produced.

6 The Permittee shall limit emissions of Sulfur Dioxide <= 4.3 pounds per hour 3-hour average, as determined byperformance test. (this is equivalent to 0.090 lb/ton BLS).

7 The Permittee shall limit emissions of Volatile Organic Compounds <= 0.090 pounds per ton of BLS (black liquorsolids) measured as carbon, excluding methane (this is equivalent to 4.3 lb/hr).

8The Permittee shall limit emissions of Sulfur - Total Reduced including H2S <= 0.033 pounds per ton of BLS(black liquor solids) measured as H2SThe BACT limit is the same as the NSPS limit.

9

The owner or operator must maintain records of parameter monitoring data required under 40 CFR Section63.864, including any period when the operating parameter levels were inconsistent with the levels establishedduring the initial performance test, with a brief explanation of the cause of the deviation, the time the deviationoccurred, the time corrective action was initiated and completed, and the corrective action taken.

10

NOx Emissions Calculation: The Permittee shall calculate NOx emissions on a semi-annual basis. The NOxemission factor shall be obtained from the most recent MPCA approved performance test. To calculate NOxemissions, the Permittee shall multiply the emission factor by the production rate of black liquor solids (virginbone dried basis). The NOx emissions shall be calculated and converted to a tons/day basis for determining thetotal NOx emissions from the facility and comparison to the NOx cap (COMG 5).

11


12

Nitrous Oxide : The Permittee shall conduct an initial performance test : Due 365 calendar days after PermitIssuance Date to measure emissions and develop an emission factor. The performance test shall be conductedat worst case conditions as defined at Minn. R. 7017.2025, subp. 2, using EPA Reference Method 7E, or othermethod approved by MPCA in the performance test plan approval.

13 Sulfur - Total Reduced including H2S : The Permittee shall conduct a performance test : Due before 09/12/2021every 60 months to measure emissions. Testing is due by the end of each 60 month period following the initialperformance test date. The performance test shall be conducted at worst case conditions as defined at Minn. R.7017.2005, subp. 8, using EPA Reference Method 16 A/C, or other method approved by MPCA in theperformance test plan approval.





40 CFR 63.866(c)(3), Minn. R.7011.7700

Minn. R. 7007.0800, subp. 6, Title ICondition: 40 CFR 52.21(o)(visibility) &Minn. R. 7007.3000


Minn. R. 7007.3000, Minn. R.7017.2020, subp. 1, Title I Condition:40 CFR 52.21(o)




12

Nitrous Oxide : The Permittee shall conduct an initial performance test : Due 365 calendar days after PermitIssuance Date to measure emissions and develop an emission factor. The performance test shall be conductedat worst case conditions as defined at Minn. R. 7017.2025, subp. 2, using EPA Reference Method 7E, or othermethod approved by MPCA in the performance test plan approval.

13

Sulfur - Total Reduced including H2S : The Permittee shall conduct a performance test : Due before 09/12/2021every 60 months to measure emissions. Testing is due by the end of each 60 month period following the initialperformance test date. The performance test shall be conducted at worst case conditions as defined at Minn. R.7017.2005, subp. 8, using EPA Reference Method 16 A/C, or other method approved by MPCA in theperformance test plan approval.


14

PM < 10 micron : The Permittee shall conduct a performance test : Due before 09/12/2021 every 60 months tomeasure emissions. Testing is due by the end of each 60 month period following the initial performance testdate. The performance test shall be conducted at worst case conditions as defined at Minn. R. 7017.2005, subp.8, using EPA Reference Methods 5 and 202, or other method approved by MPCA in the performance test planapproval.


15

Particulate Matter : The Permittee shall conduct a performance test : Due before 09/12/2021 every 60 months tomeasure Total Particulate Matter. Testing is due by the end of each 60 month period following the initialperformance test date. The performance test shall be conducted at worst case conditions as defined at Minn. R.7017.2005, subp. 8, using EPA Reference Methods 5 and 202, or other method approved by MPCA in theperformance test plan approval.


16


17

Nitrogen Oxides: The Permittee shall submit a test frequency plan : Due 60 calendar days after InitialPerformance Test Date for NOx emissions. The plan shall specify a testing frequency based on the test dataand MPCA guidance. Future performance tests based on 12-month, 36-month, or 60-month intervals, or asapplicable, shall be required upon written approval of the MPCA.

EQUI 949 1 Relative Accuracy Test Audit (RATA) Results Summary: due 30 days after end of each calendar quarter inwhich a RATA was conducted.




40 CFR 63.865(b)(1), Minn. R.7017.2020, subp. 1, Title I Condition:40 CFR 52.21(k)(modeling) & Minn. R.7007.3000

40 CFR 63.865(b)(1), Minn. R.7017.2020, subp. 1, Title I Condition:40 CFR 52.21(k)(modeling) & Minn. R.7007.3000


Minn. R. 7017.2020, subp. 1, Title ICondition: 40 CFR 52.21(o)(visibility) &Minn. R. 7007.3000

Minn. R. 7017.1180, subp. 3

Minn. R. 7017.1180, subp. 1



Subject ItemID Seq. # RequirementEQUI 949


4


5


6 Nitrogen Oxides: Emissions Monitoring: The owner or operator shall use a CEMS to measure emissions fromEQUI 16. This unit also monitors SO2 emissions.

7



8


9


10



Minn. R. 7017.1170, subp. 4a

Minn. R. 7017.1170, subp. 5a

Minn. R. 7017.1006

Minn. R. 7017.1060, subp. 1-3, Minn.R. 7017.1080

Minn. R. 7017.1090

Minn. R. 7017.1160, subp. 1-2

Minn. R. 7017.1170, subp. 2



Subject ItemID Seq. # RequirementEQUI 949

10


11





STRU 20(SV173)

1 The Permittee shall limit emissions of Sulfur Dioxide <= 0.020 pounds per ton 3-hour average of air driedunbleached pulp.

2 The Permittee shall limit emissions of Volatile Organic Compounds <= 0.20 pounds per ton 3-hour average of airdried unbleached pulp, measured as carbon, excluding methane.

3 The Permittee shall limit emissions of Sulfur - Total Reduced including H2S <= 0.12 pounds per ton 3-houraverage of air dried unbleached pulp, measured as H2S.

4 Pulping System Emissions Control: The emissions from the pulping system shall meet the requirementsspecified in 40 CFR Section 63.443(a)(1)(ii) through (iv), or as specified in 40 CFR Section 63.447 CleanCondensate Alternative.

Minn. R. 7017.1170, subp. 3

Minn. R. 7017.1180, subp. 2

Minn. R. 7017.1050, subp. 1

Minn. R. 7017.1130






Subject ItemID Seq. # RequirementSTRU 20(SV173)

3The Permittee shall limit emissions of Sulfur - Total Reduced including H2S <= 0.12 pounds per ton 3-houraverage of air dried unbleached pulp, measured as H2S.

4Pulping System Emissions Control: The emissions from the pulping system shall meet the requirementsspecified in 40 CFR Section 63.443(a)(1)(ii) through (iv), or as specified in 40 CFR Section 63.447 CleanCondensate Alternative.

5The Permittee shall limit emissions of HAPs - Total <= 400 parts per million by weight (process water).For purposes of complying with the kraft pulping condensate requirements in 40 CFR Section 63.446, thePermitee chooses to measure the total HAP concentration as methanol (see 40 CFR Section 63.457(f)(2)).

6


7


8

Sulfur - Total Reduced including H2S : The Permittee shall conduct an initial performance test : Due 365calendar days after Permit Issuance Date to measure emissions. The performance test shall be conducted atworst case conditions as defined at Minn. R. 7017.2025, subp. 2, using EPA Reference Method 16A/C, or othermethod approved by MPCA in the performance test plan approval.

9

Sulfur Dioxide: The Permittee shall submit a test frequency plan : Due 60 calendar days after Initial PerformanceTest Date for SO2 emissions. The plan shall specify a testing frequency based on the test data and MPCAguidance. Future performance tests based on 12-month, 36-month, or 60-month intervals, or as applicable, shallbe required upon written approval of the MPCA.

10


11 Sulfur - Total Reduced including H2S: The Permittee shall submit a test frequency plan : Due 60 calendar daysafter Initial Performance Test Date for TRS emissions. The plan shall specify a testing frequency based on thetest 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.

40 CFR 63.446, Minn. R. 7011.7700

40 CFR 63.443(a)(1)(iv)(B), Minn. R.7011.7700








Subject ItemID Seq. # RequirementSTRU 20(SV173)

10


11

Sulfur - Total Reduced including H2S: The Permittee shall submit a test frequency plan : Due 60 calendar daysafter Initial Performance Test Date for TRS emissions. The plan shall specify a testing frequency based on thetest 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.

STRU 75(SV903)

1

STRU 75 is an additional stack to combine stack vent 220 (ClO2 generator Delta description) and stack vent 240(Bleach plant Delta description) that has been installed to more accurately match stack parameters as modeledfor Air Toxics Review. SV 220 and SV 240 (no Tempo IDs) have been removed from the facility description and have been replacedwith STRU 75.

TREA 1(CE320)

1 ESP monitoring: The COMS for EQUI 9 shall be used to assess proper operation of this ESP.

2The Permittee shall vent emissions from EQUI 9 to TREA 1 whenever EQUI 9 operates, and operate andmaintain TREA 1 at all times that any emissions are vented to TREA 1. The Permittee shall document periods ofnon-operation of the control equipment TREA 1 whenever EQUI 9 is operating.

3 Opacity <= 13 percent opacity 3-hour block average. Opacity in excess of this limit shall be considered anexcursion under 40 CFR Section 64.6(c)(2).

4 Opacity: Continuous Monitoring: The Permittee shall continuously, or at a minimum once every 15 minutes,monitor the opacity of the ESP exhaust. See Subject Item EQUI 79 for specific COMS operating requirements.

5

Inspections: At least every two years, or more frequently if required by the manufacturer, the Permittee shallinspect the control equipment components not covered by the quarterly inspections. This includes, but is notlimited to, components that are not subject to wear or plugging including structural components, housings, andhoods. The Permittee shall maintain a written record of the inspection and any corrective actions taken resultingfrom the inspection.

6 Corrective Actions: The Permittee shall take corrective action as soon as possible if any of the following occur: - the monitored opacity, averaged over any 3-hour period, exceeds 13%; or - the ESP or any of its components are found during the inspections to need repair. Corrective actions shall return operation to within the permitted range and/or include completion of necessaryrepairs identified during the inspection, as applicable. Corrective actions include, but are not limited to, thoseoutlined in the O & M Plan for the ESP. The Permittee shall keep a record of the type and date of any correctiveaction taken for the ESP.


Minn. R. 7007.0800, subp. 2

40 CFR 64.7(a), Minn. R. 7007.0800,subp. 2, Minn. R. 7017.0200


40 CFR 64.3, Minn. R. 7017.0200

40 CFR 64.3(b)(4)(ii), Minn. R.7017.0200

40 CFR 64.3, Minn. R. 7017.0200



Subject ItemID Seq. # RequirementTREA 1(CE320)

5

Inspections: At least every two years, or more frequently if required by the manufacturer, the Permittee shallinspect the control equipment components not covered by the quarterly inspections. This includes, but is notlimited to, components that are not subject to wear or plugging including structural components, housings, andhoods. The Permittee shall maintain a written record of the inspection and any corrective actions taken resultingfrom the inspection.

6

Corrective Actions: The Permittee shall take corrective action as soon as possible if any of the following occur: - the monitored opacity, averaged over any 3-hour period, exceeds 13%; or - the ESP or any of its components are found during the inspections to need repair. Corrective actions shall return operation to within the permitted range and/or include completion of necessaryrepairs identified during the inspection, as applicable. Corrective actions include, but are not limited to, thoseoutlined in the O & M Plan for the ESP. The Permittee shall keep a record of the type and date of any correctiveaction taken for the ESP.

8

If the Permittee replaces TREA 1, the replacement control must meet or exceed the control efficiencyrequirements of TREA 1 as well as comply with all other requirements of TREA 1. Prior to making such achange, the Permittee shall apply for and obtain the appropriate permit amendment, as applicable.

If no amendment is needed for the replacement, the Permittee shall submit an electronic notice to the Agencyusing Form CR-05. The notice must be received by the Agency seven working days prior to thecommencement/start of replacement.

9

Documentation of Need for Improved Monitoring: If the Permittee fails to achieve compliance with an emissionlimitation or standard for which the monitoring did not provide an indication of an excursion or exceedance whileproviding valid data, or the results of compliance or performance testing document a need to modify the existingopacity indicator range, the Permittee shall promptly notify the MPCA and, if necessary, submit a permitamendment application to address the necessary monitoring change.

10

As required by 40 CFR Section 64.9(a)(2), for the Semi-Annual Deviations Report required by this permit and/orthe Notification of Deviations Endangering Human Health and the Environment required by this permit, asapplicable, the Permittee shall include the following related to the monitoring identified as required by 40 CFR pt.64: 1) Summary information on the number, duration, and cause of excursions or exceedances, as applicable,and the corrective action taken; and 2) Summary information on the number, duration, and cause for monitordowntime incidents.

11

The Permittee shall maintain records of monitoring data, monitor performance data, corrective actions taken,and other supporting information required to be maintained. The Permittee may maintain records on alternativemedia, provided that the use of such alternative media allows for expeditious inspection and review, and doesnot conflict with other applicable recordkeeping requirements.

15The Permittee shall operate and maintain the electrostatic precipitator (ESP) in accordance with the Operationand Maintenance (O & M) Plan. The Permittee shall keep copies of the O & M Plan available onsite for use bystaff and MPCA staff.

19Monitoring Equipment: The necessary monitoring equipment must be installed, in use, and properly maintained,including maintaining the necessary parts for routine repairs of the monitoring equipment, whenever operation ofthe monitored control equipment is required.

20 Periodic Inspections: At least once per calendar quarter, or more frequently if required by the manufacturer, thePermittee shall inspect the control equipment components that are subject to wear or plugging, for example:bearings, belts, hoses, fans, nozzles, orifices, and ducts. The Permittee shall maintain a written record of theinspection and any corrective actions taken resulting from the inspection.

40 CFR 64.7(6), Minn. R. 7017.0200

40 CFR 64.7, Title I Condition: 40 CFR52.21(j)(BACT) & Minn. R. 7007.3000

40 CFR 64.7(e), Minn. R. 7017.0200

40 CFR 64.9(a)(2), Minn. R. 7017.0200

40 CFR 64.9(b), Minn. R. 7017.0200

Minn. R. 7007.0800, subp. 14

40 CFR 64.7(b), Minn. R. 7017.0200




19

Monitoring Equipment: The necessary monitoring equipment must be installed, in use, and properly maintained,including maintaining the necessary parts for routine repairs of the monitoring equipment, whenever operation ofthe monitored control equipment is required.

20

Periodic Inspections: At least once per calendar quarter, or more frequently if required by the manufacturer, thePermittee shall inspect the control equipment components that are subject to wear or plugging, for example:bearings, belts, hoses, fans, nozzles, orifices, and ducts. The Permittee shall maintain a written record of theinspection and any corrective actions taken resulting from the inspection.

TREA 2(CE322)

6

Install, calibrate, maintain, and operate a continuous parameter monitoring system (CPMS) that can be used todetermine and record the pressure drop across the scrubber and the scrubbing liquid flow rate at least onceevery successive 15-minute period using the procedures in 63.8(c), as well as the procedures in paragraphs(e)(10)(i) and (ii).

The owner or operator of each affected source or process unit that uses an ESP, wet scrubber, RTO, or fabricfilter may monitor alternative control device operating parameters subject to prior written approval by theAdministrator.

7

Install, calibrate, maintain, and operate a monitoring device for the continuous measurement (at least once every15 minutes) of the pressure loss of the gas stream through the control equipment. The monitoring device usedfor the continuous measurement of the pressure drop of the gas stream across the scrubber must be certified bythe manufacturer to be accurate to within a gage pressure of +/-2 inches of water gage pressure.

8

Install, calibrate, maintain, and operate a monitoring device for the continuous measurement (at least once every15 minutes) of the scrubbing liquid flow rate. The monitoring device used for continuous measurement of thescrubbing liquid flow rate must be certified by the manufacturer to be accurate within +/-5 percent of the designscrubbing liquid flow rate.

9

Install, calibrate, maintain, and operate a monitoring device for the continuous measurement of the scrubbingliquid supply pressure to the control equipment. The monitoring device is to be certified by the manufacturer tobe accurate within +/-15 percent of design scrubbing liquid supply pressure. The pressure sensor or tap is to belocated close to the scrubber liquid discharge point. The Administrator may be consulted for approval ofalternative locations.

10Record once per shift, measurements obtained from the monitoring device for the continuous measurement ofthe pressure loss of the gas stream through the control equipment and from the monitoring device for thecontinuous measurement of the scrubbing liquid supply pressure to the control equipment.

11Pressure Drop >= 10 inches of water column 3-hour block average or as determined during the most recentperformance test. Three-hour block average is the average scrubber pressure drop in each three-hour block.Downtime of 15 or more minutes is not to be included as operating time.

13 Liquid Flow Rate >= 81 gallons per minute 3-hour block average, unless a new limit is set pursuant to Minn. R.7017.2025, subp. 3, based on the values recorded during the most recent MPCA-approved performance testwhere compliance was demonstrated. The new limit shall be implemented upon receipt of the Notice ofCompliance letter granting preliminary approval. The limit is final upon issuance of a permit amendmentincorporating the change.

40 CFR 64.3, Minn. R. 7017.0200

40 CFR 63.864(e)(10)&(13), 40 CFR64.7(a), Minn. R. 7011.7700

40 CFR 60.284(b)(2)(i), 40 CFR63.864(e), 40 CFR 64.7(a), Minn. R.7011.2540

40 CFR 63.864(e), 40 CFR 64.7(a),Minn. R. 7011.7700

40 CFR 60.284(b)(2)(ii), 40 CFR64.7(a), Minn. R. 7011.2450

40 CFR 60.284(c)(4), Minn. R.7011.2450

40 CFR 64.3(a), Minn. R. 7017.2025,subp. 3




11

Pressure Drop >= 10 inches of water column 3-hour block average or as determined during the most recentperformance test. Three-hour block average is the average scrubber pressure drop in each three-hour block.Downtime of 15 or more minutes is not to be included as operating time.

13

Liquid Flow Rate >= 81 gallons per minute 3-hour block average, unless a new limit is set pursuant to Minn. R.7017.2025, subp. 3, based on the values recorded during the most recent MPCA-approved performance testwhere compliance was demonstrated. The new limit shall be implemented upon receipt of the Notice ofCompliance letter granting preliminary approval. The limit is final upon issuance of a permit amendmentincorporating the change.

14

Corrective Actions: If the monitored parameter is out of the range as described above, the Permittee shall followthe facility SSM Plan and/or the O&M Plan and perform the necessary corrective action(s) as soon as possibleto get the parameters back into the correct range. The Permittee shall keep a record of the type and date of allcorrective actions taken.

15

After completion of the Initial Performance test, the Permittee is in violation of the Subpart MM Standards of 40CFR Section 63.862 if the Smelt Dissolving Tank Vent accumulates 6 or more 3-hour operating parameterexceedances within any 6-month calendar reporting period. For purposes of determining the number ofmonitoring exceedances, no more than one exceedance shall be attributed in any given 24-hour period.

16440 On-going compliance provisions. Smelt Dissolving Tank units are required to implement corrective action, whenany 3-hour average parameter value is outside the range of values established in paragraph (j) of this section.

16445

The Permittee shall vent emissions from EQUI 945 to TREA 2 whenever EQUI 945 operates, and operate andmaintain TREA 2 at all times that any emissions are vented toTREA 2. The Permittee shall document periods ofnon-operation of the control equipment TREA 2 whenever EQUI 945 is operating.

TREA 3 (Venturi Scrubber) is the backup treatment for TREA 2. This requirement applies only when EQUI 945is venting to TREA 2.

16450



16470


17450 The Permittee shall maintain records of monitoring data, monitor performance data, corrective actions taken,and other supporting information required to be maintained. The Permittee may maintain records on alternativemedia, provided that the use of such alternative media allows for expeditious inspection and review, and doesnot conflict with other applicable recordkeeping requirements.

40 CFR 64.3(a), Minn. R. 7017.2025,subp. 3

40 CFR 63.864(k), 40 CFR 63.867(c),Minn. R. 7007.0800, subp. 14, Minn. R.7007.0800, subp. 5

40 CFR 63.864(k)(2)(iii), 40 CFR63.864(k)(3)

40 CFR 63.864(k)(1)(i)


40 CFR 64.7, Title I Condition: 40 CFR52.21(b)(2)(i)(netting) & Minn. R.7007.3000, Title I Condition: 40 CFR52.21(k)(modeling) & Minn. R.7007.3000

40 CFR 64.9(a)(2), Minn. R. 7017.0200




16470


17450


17460 The Permittee shall operate and maintain the scrubber in accordance with the Operation and Maintenance (O &M) Plan. The Permittee shall keep copies of the O & M Plan available onsite for use by staff and MPCA staff.

17490Monitoring Equipment: The Permittee shall install and maintain the necessary monitoring equipment formeasuring and recording pressure drop and liquid flow rate as required by this permit. The monitoringequipment must be installed, in use, and properly maintained when the monitored scrubber is in operation.

17500 The Permittee shall calibrate the gauges at least once every 12 months and shall maintain a written record ofany action resulting from the calibration.

TREA 3(CE323)

6



7


8


9 Install, calibrate, maintain, and operate a monitoring device for the continuous measurement of the scrubbingliquid supply pressure to the control equipment. The monitoring device is to be certified by the manufacturer tobe accurate within +/-15 percent of design scrubbing liquid supply pressure. The pressure sensor or tap is to belocated close to the scrubber liquid discharge point. The Administrator may be consulted for approval ofalternative locations.

40 CFR 64.9(b), Minn. R. 7017.0200

Minn. R. 7007.0800, subp. 14

40 CFR 64.7(b), Minn. R. 7017.0200

40 CFR 64.3, Minn. R. 7017.0200

40 CFR 63.864(e)(10)&(13), 40 CFR64.7(a), Minn. R. 7011.7700


40 CFR 63.864(e), 40 CFR 64.7(a),Minn. R. 7011.7700




8


9


10Record once per shift, measurements obtained from the monitoring device for the continuous measurement ofthe pressure loss of the gas stream through the control equipment and from the monitoring device for thecontinuous measurement of the scrubbing liquid supply pressure to the control equipment.

11Pressure Drop >= 10 inches of water column 3-hour block average or as determined during the most recentperformance test. Three-hour block average is the average scrubber pressure drop in each three-hour block.Downtime of 15 or more minutes is not to be included as operating time.

13

Liquid Flow Rate >= 81 gallons per minute 3-hour block average, unless a new limit is set pursuant to Minn. R.7017.2025, subp. 3, based on the values recorded during the most recent MPCA-approved performance testwhere compliance was demonstrated. The new limit shall be implemented upon receipt of the Notice ofCompliance letter granting preliminary approval. The limit is final upon issuance of a permit amendmentincorporating the change.

14

Corrective Actions: If the monitored parameter is out of the range as described above, the Permittee shall followthe facility SSM Plan and/or the O&M Plan and perform the necessary corrective action(s) as soon as possibleto get the parameters back into the correct range. The Permittee shall keep a record of the type and date of allcorrective actions taken.

15

After completion of the Initial Performance test, the Permittee is in violation of the Subpart MM Standards of 40CFR Section 63.862 if the Smelt Dissolving Tank Vent accumulates 6 or more 3-hour operating parameterexceedances within any 6-month calendar reporting period. For purposes of determining the number ofmonitoring exceedances, no more than one exceedance shall be attributed in any given 24-hour period.

16440 On-going compliance provisions. Smelt Dissolving Tank units are required to implement corrective action, whenany 3-hour average parameter value is outside the range of values established in paragraph (j) of this section.

16445 TREA 2 (Venturi Scrubber) is the primary treatment for EQUI 945. TREA 3 is used as a backup. Thisrequirement applies only when EQUI 945 is venting to TREA 3.

The Permittee shall vent emissions from EQUI 945 to TREA 3 whenever EQUI 945 operates, and operate andmaintain TREA 3 at all times that any emissions are vented to TREA 3. The Permittee shall document periods ofnon-operation of the control equipment TREA 3 whenever EQUI 945 is operating.


40 CFR 60.284(c)(4), Minn. R.7011.2450

40 CFR 64.3(a), Minn. R. 7017.2025,subp. 3

40 CFR 64.3(a), Minn. R. 7017.2025,subp. 3

40 CFR 63.864(k), 40 CFR 63.867(c),Minn. R. 7007.0800, subp. 14, Minn. R.7007.0800, subp. 5

40 CFR 63.864(k)(2)(iii), 40 CFR63.864(k)(3)

40 CFR 63.864(k)(1)(i)




16440On-going compliance provisions. Smelt Dissolving Tank units are required to implement corrective action, whenany 3-hour average parameter value is outside the range of values established in paragraph (j) of this section.

16445

TREA 2 (Venturi Scrubber) is the primary treatment for EQUI 945. TREA 3 is used as a backup. Thisrequirement applies only when EQUI 945 is venting to TREA 3.

The Permittee shall vent emissions from EQUI 945 to TREA 3 whenever EQUI 945 operates, and operate andmaintain TREA 3 at all times that any emissions are vented to TREA 3. The Permittee shall document periods ofnon-operation of the control equipment TREA 3 whenever EQUI 945 is operating.

16450



16470


17450



17490Monitoring Equipment: The Permittee shall install and maintain the necessary monitoring equipment formeasuring and recording pressure drop and liquid flow rate as required by this permit. The monitoringequipment must be installed, in use, and properly maintained when the monitored scrubber is in operation.


1 Continuous Monitoring: The Permittee shall continuously, or at a minimum once every 15 minutes, monitor theopacity of the ESP exhaust. See Subject Item EQUI 80 for specific COMS operating requirements.

Title I Condition: Avoid major sourceunder 40 CFR 52.21(b)(1)(i) and Minn.R. 7007.3000

40 CFR 64.7, Title I Condition: 40 CFR52.21(b)(2)(i)(netting) & Minn. R.7007.3000, Title I Condition: 40 CFR52.21(k)(modeling ) & MInn. R.7007.3000

40 CFR 64.9(a)(2), Minn. R. 7017.0200

40 CFR 64.9(b), Minn. R. 7017.0200

Minn. R. 7007.0800, subp. 14

40 CFR 64.7(b), Minn. R. 7017.0200

40 CFR 64.3, Minn. R. 7017.0200



Subject ItemID Seq. # RequirementTREA 3(CE323) 17500

The Permittee shall calibrate the gauges at least once every 12 months and shall maintain a written record ofany action resulting from the calibration.

TREA 5(CE431)

1 Continuous Monitoring: The Permittee shall continuously, or at a minimum once every 15 minutes, monitor theopacity of the ESP exhaust. See Subject Item EQUI 80 for specific COMS operating requirements.

2The Permittee shall vent emissions from EQUI 16 to TREA 5 whenever EQUI 16 operates, and operate andmaintain TREA 5 at all times that any emissions are vented to TREA 5. The Permittee shall document periods ofnon-operation of the control equipment TREA 5 whenever EQUI 16 is operating.

3 Opacity <= 8.5 percent opacity 3-hour block average. Opacity in excess of this limit shall be considered anexcursion under 40 CFR Section 64.6(c)(2).

4 Opacity: Continuous Monitoring: The Permittee shall continuously, or at a minimum once every 15 minutes,monitor the opacity of the ESP exhaust. See Subject Item EQUI 80 for specific COMS operating requirements.

5

Inspections: At least once every two years, or more frequently if required by the manufacturer, the Permitteeshall inspect the control equipment components not covered by the quarterly inspections. This includes, but isnot limited to, components that are not subject to wear or plugging including structural components, housings,and hoods. The Permittee shall maintain a written record of the inspection and any corrective actions takenresulting from the inspection.

6

Corrective Actions: The Permittee shall take corrective action as soon as possible if any of the following occur:- the monitored opacity, averaged over any 3-hour period, exceeds 8.5%; or- the ESP or any of its components are found during the inspections to need repair.Corrective actions shall return operation to within the permitted range and/or include completion of necessaryrepairs identified during the inspection, as applicable. Corrective actions include, but are not limited to, thoseoutlined in the O & M Plan for the ESP. The Permittee shall keep a record of the type and date of any correctiveaction taken for the ESP.

8



9 Documentation of Need for Improved Monitoring: If the Permittee fails to achieve compliance with an emissionlimitation or standard for which the monitoring did not provide an indication of an excursion or exceedance whileproviding valid data, or the results of compliance or performance testing document a need to modify the existingpressure drop range, the Permittee shall promptly notify the MPCA and, if necessary, submit a permitamendment application to address the necessary monitoring change.

40 CFR 64.3(b)(4)(ii), Minn. R.7017.0200


40 CFR 64.3, Minn. R. 7017.0200

40 CFR 64.3(b)(4)(ii), Minn. R.7017.0200

40 CFR 64.3, Minn. R. 7017.0200

40 CFR 64.7(6), Minn. R. 7017.0200

40 CFR 64.7, Title I Condition: 40 CFRpt. 52, 21(j)(BACT) & Minn. R.7007.3000




8



9

Documentation of Need for Improved Monitoring: If the Permittee fails to achieve compliance with an emissionlimitation or standard for which the monitoring did not provide an indication of an excursion or exceedance whileproviding valid data, or the results of compliance or performance testing document a need to modify the existingpressure drop range, the Permittee shall promptly notify the MPCA and, if necessary, submit a permitamendment application to address the necessary monitoring change.

10


11

The Permittee shall maintain records of monitoring data, monitor performance data, corrective actions taken,and other supporting information required to be maintained. The Permittee may maintain records on alternativemedia, such as microfilm, computer files, magnetic tape disks, or microfiche, provided that the use of suchalternative media allows for expeditious inspection and review, and does not conflict with other applicablerecordkeeping requirements.

15The Permittee shall operate and maintain the electrostatic precipitator (ESP) in accordance with the Operationand Maintenance (O & M) Plan. The Permittee shall keep copies of the O & M Plan available onsite for use bystaff and MPCA staff.

19Monitoring Equipment: The necessary monitoring equipment must be installed, in use, and properly maintained,including maintaining the necessary parts for routine repairs of the monitoring equipment, whenever operation ofthe monitored control equipment is required.

20

Periodic Inspections: At least once per calendar quarter, or more frequently if required by the manufacturer, thePermittee shall inspect the control equipment components that are subject to wear or plugging, for example:bearings, belts, hoses, fans, nozzles, orifices, and ducts. The Permittee shall maintain a written record of theinspection and any corrective actions taken resulting from the inspection.

TREA 12(CE220)

1 The Permittee shall operate and maintain the scrubber in accordance with the Operation and Maintenance (O &M) Plan. The Permittee shall keep copies of the O & M Plan available for use by staff and MPCA staff.

2 Pressure Drop >= 3.2 inches of water column 3-hour block average (this is pressure drop of the gas stream),unless a new range is set pursuant to Minn. R. 7017.2025, subp. 3, based on the values recorded during themost recent MPCA-approved performance test where compliance was demonstrated. The new range shall beimplemented upon receipt of the Notice of Compliance letter granting preliminary approval. The range is finalupon issuance of a permit amendment incorporating the change.

40 CFR 64.7(e), Minn. R. 7017.0200

40 CFR 64.9(a)(2), Minn. R. 7017.0200

40 CFR 64.9(b), Minn. R. 7017.0200

Minn. R. 7007.0800, subp. 14

40 CFR 64.7(b), Minn. R. 7017.0200

40 CFR 64.3, Minn. R. 7017.0200

Minn. R. 7007.0800, subp. 14




1The Permittee shall operate and maintain the scrubber in accordance with the Operation and Maintenance (O &M) Plan. The Permittee shall keep copies of the O & M Plan available for use by staff and MPCA staff.

2

Pressure Drop >= 3.2 inches of water column 3-hour block average (this is pressure drop of the gas stream),unless a new range is set pursuant to Minn. R. 7017.2025, subp. 3, based on the values recorded during themost recent MPCA-approved performance test where compliance was demonstrated. The new range shall beimplemented upon receipt of the Notice of Compliance letter granting preliminary approval. The range is finalupon issuance of a permit amendment incorporating the change.

3

Liquid Flow Rate >= 95.7 gallons per minute 3-hour block average, unless a new range is set pursuant to Minn.R. 7017.2025, subp. 3, based on the values recorded during the most recent MPCA-approved performance testwhere compliance was demonstrated. The new range shall be implemented upon receipt of the Notice ofCompliance letter granting preliminary approval. The range is final upon issuance of a permit amendmentincorporating the change.(this is scrubbing liquid supply flow rate).

4 Pressure Drop Recordkeeping: Observe and record, once per operating shift, the pressure drop of the gasstream for TREA 12.

5Monitoring Equipment: (EQUI 82) The Permittee shall maintain the necessary monitoring equipment formeasuring and recording liquid supply flow rate as required by this permit. The Permittee shall continuouslymonitor the liquid supply flow rate for TREA 12.

6


7

Corrective Actions: The Permittee shall take corrective action as soon as possible if any of the following occur:- the recorded pressure drop is outside the required operating range; or- the recorded liquid supply flow rate is outside the required operating range; or- the scrubber or any of its components are found during the inspections to need repair.Corrective actions shall return the pressure drop and/or liquid flow rate to within the permitted range, and/orinclude completion of necessary repairs identified during the inspection, as applicable. Corrective actionsinclude, but are not limited to, those outlined in the O & M Plan for the scrubber. The Permittee shall keep arecord of the type and date of any corrective action taken for the scrubber.

TREA 13(CE240)

1Scrubber Parameter Values: To establish or reestablish the value for each operating parameter required to bemonitored under 40 CFR Section 63.453, the Permittee shall use the procedures described in 40 CFR Section63.453(n).

2 pH >= 11.4 (no units) 3-hour average of the gas scrubber (TREA 13) effluent.

Minn. R. 7007.0800, subp. 14

Minn. R. 7007.0800, subp. 14



Minn. R. 7007.0800, subp. 14, Minn. R.7007.0800, subps. 4-5


40 CFR 63.453(n), Minn. R. 7011.7700




1

Scrubber Parameter Values: To establish or reestablish the value for each operating parameter required to bemonitored under 40 CFR Section 63.453, the Permittee shall use the procedures described in 40 CFR Section63.453(n).

2 pH >= 11.4 (no units) 3-hour average of the gas scrubber (TREA 13) effluent.

3 Liquid Flow Rate >= 121 gallons per minute 3-hour block average or as determined during the most recentperformance test (this is gas scrubber liquid influent flow rate for TREA 13).

4

CMS for Scrubber: The Permittee shall install, calibrate, certify, operate, and maintain a continuous monitoringsystem (CMS) to measure the following parameters for the gas scrubber: (1) The pH or the oxidation/reduction potential of the gas scrubber effluent; (2) The gas scrubber vent gas inlet flow rate or gas scrubber fan operational status; and (3) The gas scrubber liquid influent flow rate. An option to the CMS requirement above, is to install, calibrate, certify, operate, and maintain a CMS tomeasure the chlorine outlet concentration of each gas scrubber used to comply with the bleaching system outletconcentration requirement specified in 40 CFR Section 63.445(c)(2).

8

Corrective Actions: If the monitored parameter is out of the range as described above, the Permittee shall followthe facility O&M Plan and perform the necessary corrective action(s) as soon as possible to get the parametersback into the correct range. The Permittee shall keep a record of the type and date of all corrective actionstaken.

TREA 15(CE341)

1



2


3Install, calibrate, maintain, and operate a monitoring device for the continuous measurement of the scrubbingliquid flow rate. The monitoring device used for continuous measurement of the scrubbing liquid flow rate mustbe certified by the manufacturer to be accurate within +/-5 percent of the design scrubbing liquid flow rate.

4 Install, calibrate, maintain, and operate a monitoring device for the continuous measurement of the scrubbingliquid supply pressure to the control equipment. The monitoring device is to be certified by the manufacturer tobe accurate within +/-15 percent of design scrubbing liquid supply pressure. The pressure sensor or tap is to belocated close to the scrubber liquid discharge point. The Administrator may be consulted for approval ofalternative locations.

40 CFR 63.453(c)&(n)), Minn. R.7007.0800, subp. 14, Minn. R.7011.7700

40 CFR 63.453(c)&(n)), Minn. R.7007.0800, subp. 14, Minn. R.7011.7700

40 CFR 63.453(a),(c),&(d), Minn. R.7011.7700


40 CFR 63.864(e)(10)&(13), 40 CFR64.7(a), Minn. R. 7011.7700


40 CFR 63.864(e), 40 CFR 64.7(a),Minn. R. 7011.7700




3

Install, calibrate, maintain, and operate a monitoring device for the continuous measurement of the scrubbingliquid flow rate. The monitoring device used for continuous measurement of the scrubbing liquid flow rate mustbe certified by the manufacturer to be accurate within +/-5 percent of the design scrubbing liquid flow rate.

4


5

Record once every 15 minutes as equally spaced intervals, or as an arithmetic or integrated three-hour blockaverage, measurements obtained from the monitoring device for the continuous measurement of the pressureloss of the gas stream through the control equipment and from the monitoring device for the continuousmeasurement of the scrubbing liquid supply pressure to the control equipment.

6

After completion of the Initial Performance test, the Permittee is in violation of the Subpart MM Standards of 40CFR Section 63.862 if the Lime Kiln Scrubber accumulates 6 or more 3-hour operating parameter exceedanceswithin any 6-month calendar reporting period. For purposes of determining the number of monitoringexceedances, no more than one exceedance shall be attributed in any given 24-hour period.

7

Corrective Actions: If the monitored parameter is out of the range as described above, the Permittee shall followthe facility O&M Plan and the SSMP and perform the necessary corrective action(s) as soon as possible to getthe parameters back into the correct range. The Permittee shall keep a record of the type and date of allcorrective actions taken.

8 On-going compliance provisions. Lime kiln units are required to implement corrective action, when any 3-houraverage parameter value is outside the range of values established in paragraph (j) of this section.

9

SSM Excess Emissions Report: Report any/all excess emissions quarterly within 30 days following the end ofthe calendar quarter. The report must contain the required elements specified in 40 CFR Section 63.10(c).Reporting excess emissions below the violation thresholds of 63.864(k) does not constitute a violation of theSubpart MM standard. When no excess emissions have occurred, the Permittee shall submit a semi-annualreport stating that no excess emissions have occurred during the reporting period. Subpart MM excessemission reports may be combined with Subpart S semi-annual excess emission reports.

10The Permittee shall vent emissions from EQUI 13 to TREA 15 whenever EQUI 13 operates, and operate andmaintain TREA 15 at all times that any emissions are vented to TREA 15 . The Permittee shall documentperiods of non-operation of the control equipment TREA 15 whenever EQUI 13 is operating.

15 Water pressure >= 302 psi (gauge) 3-hour block average, unless a new range is set pursuant to Minn. R.7017.2025, subp. 3 based on the values recorded during the most recent MPCA-approved performance testwhere compliance was demonstrated. The new range shall be implemented upon receipt of the Notice ofCompliance letter granting preliminary approval. The range is final upon issuance of a permit amendmentincorporating the change. This pressure is the scrubber liquid supply pressure (at nozzle). (EPA letter dated 12/8/04 allowing this under 40 CFR Section 63.864(j)(2) and (3) (ADI Control NumberM050014)).


40 CFR 60.284(c)(4), 40 CFR63.864(a)(2), 40 CFR 63.864(e), 40CFR 64.3(a), Minn. R. 7011.2459

40 CFR 63.864(k)(2)(iii), 40 CFR63.864(k)(3)

40 CFR 63.864(k), Minn. R. 7007.0800,subp. 14, Minn. R. 7007.0800, subp. 5

40 CFR 63.864(k)(1)(ii), Minn. R.7011.7700

40 CFR 63.867(c), Minn. R. 7011.7700





10

The Permittee shall vent emissions from EQUI 13 to TREA 15 whenever EQUI 13 operates, and operate andmaintain TREA 15 at all times that any emissions are vented to TREA 15 . The Permittee shall documentperiods of non-operation of the control equipment TREA 15 whenever EQUI 13 is operating.

15

Water pressure >= 302 psi (gauge) 3-hour block average, unless a new range is set pursuant to Minn. R.7017.2025, subp. 3 based on the values recorded during the most recent MPCA-approved performance testwhere compliance was demonstrated. The new range shall be implemented upon receipt of the Notice ofCompliance letter granting preliminary approval. The range is final upon issuance of a permit amendmentincorporating the change. This pressure is the scrubber liquid supply pressure (at nozzle). (EPA letter dated 12/8/04 allowing this under 40 CFR Section 63.864(j)(2) and (3) (ADI Control NumberM050014)).

16

Liquid Flow Rate >= 403 gallons per minute 3-hour block average, unless a new limit is set pursuant to Minn. R.7017.2025, subp. 3, based on the values recorded during the most recent MPCA-approved performance testwhere compliance was demonstrated. The new limit shall be implemented upon receipt of the Notice ofCompliance letter granting preliminary approval. The limit is final upon issuance of a permit amendmentincorporating the change.(EPA letter dated 12/8/04 allowing this under 40 CFR Section 63.864(j)(2) and (3) (ADI Control NumberM050014)).

18



20


21




40 CFR 63.864(j)(2)&(3), 40 CFR64.3(a), Minn. R. 7017.2025, subp. 3

40 CFR 63.864(j)(2)&(3), 40 CFR64.3(a), Minn. R. 7017.2025, subp. 3

40 CFR 64.7, Title I Condition: 40 CFR52.21(b)(2)(i)(netting) & MInn. R.7007.3000, Title I Condition: 40 CFR52.21(k)(modeling) & Minn. R.7007.3000

40 CFR 64.9(a)(2), Minn. R. 7017.0200

40 CFR 64.9(b), Minn. R. 7017.0200

Minn. R. 7007.0800, subp. 14

40 CFR 64.3, Minn. R. 7017.0200



Attachment 4: CAM Plan


Boise White Paper, LLC- International Falls, MN CAM Plan

Revision 7 - July 6, 2016

AQ ID 01700002 BOISE WHITE PAPER, LLC – International Falls Unit/Pollutant for CAM Plan: Boiler #2 /PM AND Boiler #2 /PM10 I. BACKGROUND

A. Emission Unit:

Boiler #2 – EQUI 16, STRU 146

B. Applicable Regulation, Emission Limit and Monitoring Requirements:

Applicable Regulations/Emission Limits:

Title I Limits - BACT · PM – 13.0 lbs/hr · PM10 – 11.7 lbs/hr

Monitoring Requirements:

· Opacity – EQUI 80

The existing Title V permit has opacity monitoring requirements.

C. Control Technology (pollutant controlled)

TREA 5 – High Efficiency Electrostatic Precipitator (PM/PM10)

II. MONITORING APPROACH

Boise proposes to use opacity as an indicator that will act as a trigger to take action at the ESP. Boiler #2 is subject to an opacity limit under NESHAPS Subpart DDDDD as well as BACT requirements. An opacity COMs has been used in the past and will continue to be used to show compliance with that limit. Unexpected or sudden increases in opacity that persist for more than very short periods of time are indications that there may be an ESP malfunction. Such increases will be used to trigger investigation of the ESP and prompt any necessary corrective actions. While opacity may be a useful indicator of ESP malfunction, it is not a measure of mass-based emissions and cannot be used to identify exceedance events for mass-based permit limits. NESHAPS Subpart DDDDD specifies <= 10% opacity on a daily block average and has a PM limit of 0.037 #/MMBTU. The existing PM BACT limit of 13 #/hour is equivalent to 0.033 #/MMBTU. Our existing BACT PM limit is therefore approximately 11% more restrictive than the NESHAPS Subpart DDDDD limit. Boise will investigate elevated opacity as an early warning of potential problems with ESP operation when opacity reaches 8.5% on a 3-hour block average.


1. Indicator: Changes in Opacity - magnitude and duration 2. Indicator Range: Monitored opacity, measured as any 3-hour block average

(during Boiler 2 operation) exceeding 8.5%, will be investigated. 3. Performance Criteria:

· Data Representativeness – Opacity is caused by interaction of particles with light (transmissivity). Therefore, changes in opacity may be an indicator of ESP performance. The COMs is situated in a location believed to provide an accurate representation of stack opacity.

· Verification of Operational Status – COMs requirements included elsewhere in the permit for opacity compliance will address operational status (Total Facility Requirements)

· QA/QC – COMs requirements included elsewhere in the permit for opacity compliance will address QA/QC (Total Facility Requirements)

· Monitoring Frequency – Continuous.


AQ ID 01700002 BOISE WHITE PAPER, LLC – International Falls Unit/Pollutant for CAM Plan: Recovery Furnace /PM AND Recovery Furnace /PM10 I. BACKGROUND

A. Emission Unit:

Recovery Furnace – EQUI 9, STRU 150



Title I Limits - BACT and Modeling · PM – 27.0 lbs/hr · (More stringent than NSPS Subpart BB and NESHAPs Subpart MM) · PM10 – 19.2 lbs/hr


· Opacity – EQUI 79

The existing Title V permit has opacity monitoring requirements.


TREA 1 – High Efficiency Electrostatic Precipitator (PM/PM10) II. MONITORING APPROACH

Boise proposes to use opacity as an indicator that will act as a trigger to take action at the ESP. The Recovery Furnace is subject to an opacity limit under NESHAPS Subpart MM. An opacity COMs has been used in the past and will continue to be used. Unexpected or sudden increases in opacity that persist for more than very short periods of time are indications that there may be an ESP malfunction.

Changes in opacity will be used to trigger action by plant personnel to inspect and correct as necessary ESP functionality. While opacity may be a useful indicator of ESP malfunction, it is not a measure of mass based emissions and cannot be used to identify exceedance events for mass based permit limits. During recent particulate performance testing, opacity ranged from 3.9% to 4.2%, and PM emissions were measured at 27% of the limit. Therefore if opacity goes as high as 13%, the PM emissions are still very likely to be comfortably below the emission limit. Elevated opacity is used as an early warning of potential problems with the ESP operation.


1. Indicator: Changes in Opacity - magnitude and duration 2. Indicator Range: Monitored opacity, measured as any 3-hour block average

(during recovery furnace operation) exceeding 13%, will be investigated.

3. Performance Criteria:

· Data Representativeness – Opacity is caused by interaction of particles with light (transmissivity). Therefore, changes in opacity may be an indicator of ESP performance. The COMs is situated in a location believed to provide an accurate representation of stack opacity.

· Verification of Operational Status – COMs requirements included elsewhere in the permit for opacity compliance will address operational status (Total Facility Requirements)

· QA/QC – COMs requirements included elsewhere in the permit for opacity compliance will address QA/QC (Total Facility Requirements)

· Monitoring Frequency – Continuous


AQ ID 01700002 BOISE WHITE PAPER, LLC – International Falls Unit/Pollutant for CAM Plan: Smelt Dissolving Tank/PM AND Smelt Dissolving Tank/PM10 I. BACKGROUND

A. Emission Unit:

Smelt Dissolving Tank – EQUI 945, STRU 110



EPA approved alternative MACT limits · PM – 0.12 lbs/ton Black liquor solids fired (dry virgin). · (More stringent than NSPS Subpart BB and NESHAPs Subpart MM) · PM10 – 0.12 lbs/ton Black liquor solids fired (dry virgin).

Title I Limits – Modeling and Netting · PM – 7.3 lbs/hr · PM10 – 7.3 lbs/hr


· Pressure Drop – EQUI 116 · Scrubber Flow Rate – EQUI 81

The existing Title V permit has requirements for monitoring pressure drop, and flow rate in accordance with NSPS Subpart BB and NESHAPs Subpart MM.


TREA 2 – Venturi Scrubber (PM/PM10)

TREA 3 – Venturi Scrubber (alternate to TREA 2) (PM/PM10) II. MONITORING APPROACH

Boise proposes to use monitoring systems for pressure drop and scrubber flow rate for purposes of ensuring that the scrubber is operating as required. These are key operating parameters for the venturi scrubber. There are NESHAPs limits from Subpart MM and related monitoring in the permit – pressure drop and scrubber liquid flow rate. The NESHAPs monitoring meets current CAM requirements as that standard was issued after Nov. 15, 1990. However, the BACT and modeling based limits are less than the NESHAPs limits and therefore CAM must be satisfied for them. The NESHAPs requirements address the critical operating parameters for PM and PM10 for a scrubber. The indicator ranges are set based on testing and therefore will address the lower emission limits.


1. Indicators:

· Pressure Drop · Scrubber Flow

2. Indicator Range: Indicator thresholds set based on the average values recorded during most recent performance test

· Pressure Drop: inches water column using 3-hour Block Average · Flow Rate: gallons/minute using 3-hour Block Average.


· Data Representativeness – See QA/QC below. The two types of data address all portions of the scrubbing system.

· Verification of Operational Status – records required are met by continuous measurement devices. A computer file with calculated 3-hr rolling averages are required.

· QA/QC – Calibration (or similar preventive maintenance) required annually. Also:

· Scrubber Flow – Accuracy required to be +/- 5% of the design scrubbing liquid supply flow.

· Pressure Drop – Accuracy required to be +/- 2 inches water gage. · Monitoring Frequency – Once every successive 15-minute period

Note that QA/QC criteria for the parameter monitoring systems are set by NESHAPs subpart MM


AQ ID 01700002 BOISE WHITE PAPER, LLC – International Falls Unit/Pollutant for CAM Plan: Lime Kiln/PM AND Lime Kiln/PM10 I. BACKGROUND

A. Emission Unit:

Lime Kiln – EQUI 13, STRU 111



Limit – NSPS BB · PM – <= 0.066 grains/dry standard cubic foot @10% oxygen

Title I Limits – Modeling and Netting · PM – 12.7 lbs/hr · PM10 – 12.7 lbs/hr


· Scrubber Flow Rate – EQUI 126 · Scrubber Supply Pressure – EQUI 108

The existing Title V permit has requirements for monitoring scrubber supply pressure and liquid flow rate in accordance with NSPS Subpart BB and NESHAPs Subpart MM.


TREA 15 – Wet Scrubber – High Efficiency (PM/PM10)

II. MONITORING APPROACH

Boise proposes to use monitoring systems for scrubber supply pressure and scrubber flow rate for purposes of ensuring that the scrubber is operating as required. These are key operating parameters for the venturi scrubber. There are NESHAPs limits from Subpart MM and related monitoring in the permit – pressure drop and scrubber liquid flow rate. The NESHAPs monitoring meets current CAM requirements as that standard was issued after Nov. 15, 1990. The NESHAPs requirements address the critical operating parameters for PM and PM10 for a scrubber. The indicator ranges are set based on testing and therefore will address the lower emission limits.


1. Indicators:

· Pressure Drop · Scrubber Flow

2. Indicator Range: Indicator thresholds set based on the average values recorded during most recent performance test.

· Supply Pressure: psi using 3-hour Block Average · Flow Rate: gallons/minute using 3-hour Block Average.


· Data Representativeness – See QA/QC below. The two types of data address all portions of the scrubbing system.

· Verification of Operational Status – records required are met by continuous measurement devices. A computer file with calculated 3-hr rolling averages are required.

· QA/QC – Calibration (or similar preventive maintenance) required annually. Also:

· Scrubber Flow – Accuracy required to be +/- 5% of the design scrubbing liquid supply flow.

· Supply Pressure – Accuracy required to be +/- 15% of the design scrubbing liquid supply pressure.

· Monitoring Frequency – Once every successive 15-minute period

Note that QA/QC criteria for the parameter monitoring systems are set by NESHAPs subpart MM

Attachment 5: Steam Turbine Project Air Permitting Analysis


Boise White Paper 400 Second Street International Falls, MN 56649 218-285-5011

Project Air Permitting Analysis

Project Title: Steam Turbine Project 2015 Review Date: May 27, 2014 Reviewed By: John Piotrowski, Rich Garber, MaryLee Ransmeier, Mark Hauke, Dave Reimer, Tanya Anderson, Jason Lindquist Project Purpose: Improve electrical generation efficiency

Is PSD permitting required? No

1. Is the project a physical change or change in method of operation that does not include aspecific exemption identified in 40 CFR 52.21? No.

a. Is the project considered Routine Maintenance, Repair, and Replacement (RMRR)?No.What is the nature of the project? Consider the following:

i. Whether major components of the facility are being modified or replaced;specifically, whether the units are of considerable size, function, orimportance to the operation of the facility considering the type of industryinvolved.

ii. Whether the change requires pre-approval of a state commission.iii. Whether the source itself has characterized the change as non-routine in any

of its own documentsiv. Whether the change could be performed during full functioning of the facility

or while it was in full working orderv. Whether the materials, equipment, and resources necessary to carry out the

planned activities are already onsite.A refurbished 40 Megawatt high pressure steam turbine will replace existinglow pressure steam turbines 1, 2, 3, and 4. The old turbines were originallyrated at 15 MW each but have declined in efficiency. The replacement turbinewill operate on high pressure steam provided from the Recovery Furnace. Noincreased black liquor firing is required. Existing facilities will be utilized.Incremental low pressure steam for mill processes will be generated withnatural gas on Boilers 1 and 3. PSD analysis indicates that the no PSD levelincreases will occur as a result of additional natural gas combustion.(Worksheet analysis attached or in file-Barr Engineering) No additionalpermits are required for the project.

What is the extent of the project? Consider the following: i. Whether the entire emission unit will be replaced.ii. Whether the change will take significant time to perform.iii. Whether the collection of activities, taken as a whole, constitutes a non-

routine effort, notwithstanding that individual elements could be routine.iv. Whether the change requires the addition of parts to existing equipment.

No changes to emission units or capacity will occur. No additional equipmentis required other than the turbine installation within an existing building. Thisis not routine for the location.

What is the purpose of the project? Consider the following: i. Whether the purpose of the effort is to extend the useful life of the unit,

similarly, whether the source proposes to replace the unit at the end of itsuseful life

ii. Whether the modification will keep the unit operating in its present condition, or whether it will allow enhanced operation (e.g., will it permit increased capacity, operating rate, utilization, or fuel adaptability) The turbines being retired are not included in any environmental permits. The size of the new unit is not subject to MN or federal regulations. (> 50 MW for New large unit installation requirements. MN Statues 2013, 216.B2421)

What is the frequency of the project? Consider the following: i. Whether the change is performed frequently in a typical unit’s life

Turbine retirement only occurs once. This is not an emission source. What is the cost of the project? Consider the following:

i. Whether the change will be costly, both in absolute terms and relative to the cost of replacing the unit.

ii. Whether a significant amount of the cost of the change is included in the source’s capital expense, or whether the change can be paid for out of the operation budget (i.e., whether the costs are reasonably reflective of the costs originally projected during the source’s or unit’s design phase as necessary to maintain the day-to-day operation of the source). $25 MM

2. Does the change result in a significant emissions increase of a regulated NSR pollutant? No – See emissions calculations

3. Does the change result in a significant net emissions increase of a regulated NSR pollutant

from the major stationary source? No – See emissions calculations

Does the project trigger New Source Performance Standards? No 1. Is this a modification of an NSPS Source? No

a. Construction (i.e. built after the effective date in appropriate subparts):

___________________________________________________________________ ___________________________________________________________________

b. Reconstruction (i.e. replacement of components of an existing facility with fixed capital costs of the new components >50 % of the fixed capital cost required to construct a comparable new facility): this project does not trigger definition of reconstruction. ___________________________________________________________________ ___________________________________________________________________

c. Modification (i.e. physical or operational change that increases the maximum emission rate of pollutant): ___________________________________________________________________ ___________________________________________________________________

Is State only permitting required? No. There will be no physical or operating changes to any permitted emission source or pollution control equipment that requires permitting or notice to MPCA. Regulatory analysis and attached memo from Dawn Blancaflor includes MN Environmental Pre-Screening Form demonstrating no State permits or notifications are required.

Page 2 of 3

1. Administrative Amendment? No2. Minor Amendment? No3. Moderate Amendment? No4. Major Amendment? No5. State Required Notification? NoIs there any impact on facility modeling? No1. Are there any changes in stack height? No2. Are there any changes in stack discharge diameter? No3. Are there any changes in stack exhaust temperature? No

______________________________

Is there any impact on the facility’s Air Toxic Review? No – There is not a change to air toxics emissions

1. Are there any changes to toxic air emissions? No

Summary:

________________________________________________________________________________________________________________________________________________________

Page 3 of 3

Attachment 6: Application and Additional Points


Points Calculator

(DQ Points)

1) AI ID No.: 443 Total Points 372) Facility Name: Boise White Paper LLC - Intl Falls 3) Small business? y/n? n 4) Air Project Tracking Numbers (including 4883, 4096, 3750, 3455, 2887, 5326, 5543 5) Date of each Application Received:6) Final Permit No. 07100002-0147) Permit Staff Krueger, Brady

Total TotalApplication Type Air Project Tracking No. Tempo Activity ID Qty. Points Points Additionl Cost DetailsAdministrative Amendment 3455, 2887 IND20110001, IND20090001 2 1 2 570.00$ paid at time of applicMinor Amendment 4 0 -$ Applicability Request 10 0 -$ Moderate Amendment 15 0 -$ Major Amendment 5543 IND20160001 1 25 25 7,125.00$ paid at time of applicIndividual State Permit (not reissuance) 50 0 -$ Individual Part 70 Permit (not reissuance) 75 0 -$

Additional PointsModeling Review 15 0 -$

BACT Review 15 0 -$ LAER Review 15 0 -$ CAIR/Part 75 CEM analysis 10 0 -$ NSPS Review 10 0 -$ NESHAP Review 10 0 -$ Case-by-case MACT Review 20 0 -$ Netting 10 0 -$ Limits to remain below threshold 5543 IND20160001 1 10 10 2,850.00$ Plantwide Applicability Limit (PAL) 20 0 -$ AERA review 15 0 -$ Variance request under 7000.7000 35 0 -$ Confidentiality request under 7000.1300 2 0 -$ EAW reviewPart 4410.4300, subparts 18, item A; and 29 15 0 -$ Part 4410.4300, subparts 8, items A & B; 10, items A to C; 16, items A & D; 17, items A to C & E to G; and 18, items B & C

35 0 -$

Part 4410.4300, subparts 4; 5 items A & B; 13; 15; 16, items B & C; and 17 item D

70 0 -$

Add'l Points 10

NOTES:

Total Additional Points Fee is $2,850.00

Attachment 2: Subject item inventory and facility requirements
