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Technical Support Document, Permit Action Number: 12300694‐004 of 26

TECHNICAL SUPPORT DOCUMENT

For DRAFT/PROPOSED AIR EMISSION PERMIT NO. 12300694‐004

This technical support document (TSD) is intended for all parties interested in the draft/proposed permit and to meet the requirements that have been set forth by the federal and state regulations (40 CFR § 70.7(a)(5) and Minn. R. 7007.0850, subp. 1). The purpose of this document is to provide the legal and factual justification for each applicable requirement or policy decision considered in the preliminary determination to issue the draft/proposed permit. 1. General Information 1.1 Applicant and Stationary Source Location:

Table 1. Applicant and Source Address

Applicant/Address Stationary Source/Address (SIC Code: 8731, 2672)

3M Company 3M Center Bldg. 224‐5W‐03 St. Paul, MN 55144

3M ‐ Administrative Offices ‐ Maplewood I‐94 & McKnight Rd Maplewood Ramsey County, Minnesota 55144

Contact: Tina Mumm Phone: 651‐737‐3606

1.2 Facility Description 3M Company (3M) operates a research and development complex located at I‐94 and McKnight Road in Maplewood, Minnesota (3M Center ‐ Maplewood). The facility at this location is one stationary source under New Source Review (NSR), the Part 70 Operating Permit Program, and the National Emissions Standards for Hazardous Air Pollutants for Source Categories (NESHAPs) but is covered by two separate permits: 3M ‐ R & D Facility ‐ Maplewood Bldg 201 (R&D permit) covered by Permit No. 12300015, and 3M ‐ Administrative Offices – Maplewood (Administrative Offices permit) covered by this permit. The R&D permit covers the pilot plants, the laboratories, and maintenance operations. The Administrative Offices permit covers the boilers, generators, tanks, and cooling towers at the facility.

The main pollutants from the R&D operations are volatile organic compounds (VOC), hazardous air pollutants (HAP), carbon monoxide (CO), nitrous oxides (NOx), sulfur dioxide (SO2), particulate matter (PM), particulate matter less than 10 microns in diameter (PM10), and particulate matter less than 2.5 microns in diameter (PM2.5).

The main pollutants from operations covered by the Administrative Offices permit are from combustion of No. 2 fuel oil, natural gas and ultra‐low sulfur diesel. This includes emissions of volatile organic compounds (VOC), hazardous air pollutants (HAP), carbon monoxide (CO), nitrous oxides (NOx), sulfur dioxide (SO2), particulate matter (PM), particulate matter less than 10 microns in diameter (PM10), and particulate matter less than 2.5 microns in diameter (PM2.5).

The existing permitted potential to emit for the 3M Center is greater than the Prevention of Significant Deterioration (PSD), Part 70, and NESHAP major source thresholds.


1.3 Description of the Activities Allowed by this Permit Action This permit action is the Reissuance of the Part 70 operating permit. The MPCA has a combined operating and construction permitting program under Minnesota Rules Chapter 7007, and under Minn. R. 7007.0800. Under that authority, this permit action authorizes construction. Under that authority, this permit action authorizes construction of an emergency generator for Building 280 (EU055). 1.4 Description of Notifications and Applications Included in this Action In addition to reissuing the Part 70 operating permit, this permit action incorporates the following amendment applications, notifications and permit reopenings:

Table 2. Notifications and Applications Included in this Action Date Received DQ# Application/Notification Type and description

6/18/2008 2123 Part 70 Reissuance Application.

9/26/2012 4131 Major amendment to incorporate limits from modeling. Limit fuel to No. 2 fuel oil and natural gas for boilers 3, 4, and 5 (EU003, EU004 and EU005); restrict generators at Building 243 to operation of no more than 3 generators at one time; remove EU026 from the permit.

2/26/2014 4689 Moderate amendment for construction of a new emergency generator for Building 280.

11/21/2008 2332 Minor amendment for replacement of emergency generator EU013 with EU052.

11/10/2010 3303 Administrative amendment to update facility contact information. Note: an administrative amendment is not needed for this purpose. This permit action closes this amendment application for administrative purposes.

7/9/2014 4862 Minor amendment for replacement of emergency generator EU022 with EU051.

11/4/2005 1231 Notification that 3M – Administrative Offices – Maplewood has generators subject to the requirements of 40 CFR pt. 63, subp. ZZZZ.

2/2/2010 4796 Notification for replacement of emergency generator EU022 with EU051. The replacement does not qualify as a notification and 3M is required to submit a minor amendment to make this change (see DQ4862).

6/18/2008 4797 Notification for replacement of emergency generators EU023 and EU024 with EU048 and EU049, respectively.

9/10/2008 2222 Reopening to update the facility description for continuous emissions systems (CEMS) (MR001 and MR003) and continuous opacity monitoring systems (COMS) (MR002) serving Boiler No. 6 (EU006/SV006).

1.5 Additional Changes made by this Permit Action 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 requirements to submit a dispersion modeling protocol and modeling results for PM10, SO2 and NOx were removed.

o On 3/26/2012, the Permittee completed the requirement to conduct dispersion modeling for PM10.

o Previously, 3M was required under MPCA’s Title V policy to conduct NO2 modeling because PM10 modeling was triggered and the potential to emit (PTE) of NO2 was greater than 100 tons per year. Our implementation of this portion of our Title V


modeling policy has recently evolved and, as a result, the requirement to conduct NO2 modeling no longer exists under these circumstances.

o In preparation for the State Implementation Plan (SIP) for SO2, the MPCA conducted preliminary SO2 modeling. The 3M Center in Maplewood (includes both the Administrative Offices and the Research and Development campuses) was included in the modeling conducted for SO2 SIP purposes. The results from that modeling show that the 3M Center is in compliance with the SO2 NAAQS; therefore, no addition Title V modeling is required at the 3M Center at this time.

Allowable fuels for boilers have been changed. For boilers that were previously allowed to burn No. 6 fuel oil, only No. 2 fuel oil and natural gas are allowed. The sulfur content of fuel oil has also been reduced to 0.05%.

Requirements to submit one‐time submittals or notifications that have been completed have been removed.

A number of existing engines at this facility are subject to National Emission Standards for Hazardous Air Pollutant requirements (NESHAP) for reciprocating internal combustion engines (RICE). 3M submitted a notification on11/4/2005 indicating which units are required to comply with the RICE NESHAP. The applicable requirements have been added to this draft/proposed permit as part of this permit action (DQ 1231).

The facility description was updated to include the new NOx continuous emissions monitor (CEM) and the new continuous opacity monitor (COM) for EU006 (Boiler 6) (DQ 2222).

Requirements for units that are no longer on site have been removed from the permit.

Cooling Towers were previously listed as insignificant activities in the facility description. These units have been moved to Appendix II.

1.6 Facility Emissions:

Table 3. Title I Emissions Summary – EU055 – Moderate Amendment (DQ 4689)

Pollutant

Unlimited Potential Emissions from the Modification**

(tpy)

Limited Potential Emissions from the Modification

(tpy)

NSR/112(g) Threshold for Major Modification

(tpy)

NSR/112(g) Review Required? (Yes/No)

PM 0.08 0.01 25 No

PM10 0.08 0.01 15 No

PM2.5 0.08 0.01 10 No

NOX 2.65 2.65 40 No

SO2 0.27 0.27 40 No

CO 1.45 0.14 100 No

Ozone (VOC) 0.16 0.16 40 No

CO2e* 288 288 75,000 No

Single HAP (Benzene)

1.37*10‐3 1.37*10‐3 10 No

Total HAPs 2.62*10‐3 2.62*10‐3 25 No

*Carbon dioxide equivalents as defined in Minn. R. 7007.0100.


** Unlimited potential emissions calculated based on 500 hours/year of operation for emergency generators. This is consistent with the September 6, 1995 Memo from EPA titled Calculating Potential to Emit (PTE) for Emergency Generators.

Table 4a. Non‐Title I Emissions Increase Summary – EU055 – Moderate Amendment (DQ 4689)

Pollutant

After Change (lb/hr)

Before Change (lb/hr)

Net Change* (lb/hr)

Insignificant Modification Thresholds (lb/hr <)

Minor and Moderate

Amendment Thresholds (lb/hr < or >)

Type of Amendment (Minor or Moderate)

PM10 0.05 0 0.05 0.855 3.42 NA

NOx 10.58 0 10.58 2.28 9.13 Moderate

SO2 1.07 0 1.07 2.28 9.13 NA

CO 0.58 0 0.58 5.70 22.80 NA

VOC 0.63 0 0.63 2.28 9.13 NA

Table 4b. Non‐Title I Emissions Increase Summary – EU052 – Minor Amendment (DQ 2332)

Pollutant



Net Change* (lb/hr)


Minor and Moderate


Type of Amendment (Minor or Moderate)

PM10 0.06 0 0.06 0.855 3.42 NA

NOx 3.72 0 3.72 2.28 9.13 minor

SO2 6.0*10‐4 0 < 0.001 2.28 9.13 NA

CO 0.45 0 0.45 5.70 22.80 NA

VOC 0.14 0 0.14 2.28 9.13 NA

Table 4c. Non‐Title I Emissions Increase Summary – EU051 – Minor Amendment (DQ 4862)

Pollutant



Net Change* (lb/hr)


Minor and Moderate


Type of Amendment**

(Minor or Moderate)

PM10 0.20 0.48 ‐0.28 0.855 3.42 NA

NOx 3.97 16.54 ‐12.57 2.28 9.13 NA

SO2 6.39*10‐5 2.79 ‐2.79 2.28 9.13 NA

CO 3.47 3.79 ‐0.32 5.70 22.80 NA

VOC 0.43 0.49 ‐0.05 2.28 9.13 NA

*The term ‘Net Change’ is not equivalent to ‘Net Emissions Increase’ as defined at 40 CFR Section 52.21(b)(3).

** Minor amendment triggered due to change in permit conditions.

Table 5. Total Facility Potential to Emit Summary

PM tpy

PM10 tpy

PM2.5 tpy

SO2 tpy

NOx tpy

CO tpy

CO2e tpy

VOC tpy

Single HAP** tpy

AllHAPs*** tpy

Total Facility Limited Potential Emissions

78.6 57.7 42.2 160.6 903.8 363.4 590,214 28.2 7.24 8.5

Total Facility Actual Emissions (2012)

0.6 0.6 0.5 0.9 104.5 35.4 * 4.9 *


*Not reported in MN emission inventory. **Single HAP is Hexane. ***When HAPs from the 3M – R&D Facility – Maplewood permit are included the facility is considered a major source under 40 CFR Part 63.

Table 6. Facility Classification Classification Major Synthetic Minor/Area Minor/Area

PSD X

Part 70 Permit Program X

Part 63 NESHAP X

2. Regulatory and/or Statutory Basis New Source Review The facility is an existing major source under New Source Review regulations. No changes to the source status are authorized by this permit. The potential emissions from the modification (moderate amendment) are not subject to NSR as shown in Table 4a because the limited emissions do not constitute a major modification; therefore, this permit action is not subject to NSR. The potential emissions from the modification (minor amendment) are not subject to NSR as shown in Table 4b because the limited emissions do not constitute a major modification; therefore, this permit action is not subject to NSR. The potential emissions from the modification (minor amendment) are not subject to NSR as shown in Table 4c because the limited emissions do not constitute a major modification; therefore, this permit action is not subject to NSR. Part 70 Permit Program The facility is a major source under the Part 70 permit program. No changes to the source status are authorized by this permit. New Source Performance Standards (NSPS) The proposed emergency generator (EU055) is subject to the NSPS requirements for Compression Ignition (CI) Internal Combustion Engines (ICE) (subp. IIII). The applicable requirements are listed under GP004 of this draft/proposed permit. The following existing engines are also subject to the NSPS subp. IIII requirements for CI ICE: EU047‐EU049, EU051 and EU054. The applicable NSPS requirements are listed under subject item in the draft/proposed permit. These requirements were added to the permit as part of this permit action. The following existing engines are subject to the NSPS subp. JJJJ requirements for SI ICE: EU052 and EU053. The applicable NSPS requirements are listed under subject item in the draft/proposed permit. These requirements were added to the permit as part of this permit action. Existing boilers greater than 100 MMBtu/hr constructed after June 19, 1984 are subject to the NSPS requirements for Industrial‐Commercial‐Institutional Steam Generating Units (subp. Db). Boilers 6 and 7


(EU006 and EU043, respectively) are subject to this standard. No changes to the permit were made as part of this permit action. The existing tanks at the facility are not subject to the Standards of Performance for Volatile Organic Liquid Storage Vessels (40 CFR pt. 60, subps. K, Ka or Kb) because the tank capacity is below the threshold (TK002 and TK006) or the contents of the tank is not regulated by the standards (TK003 and TK007). Updates to requirement language were made as part of this permit action. National Emission Standards for Hazardous Air Pollutants (NESHAP) The facility, which includes the sources covered by this permit and the sources covered by Permit No. 12300015, is a major source under Part 63 (NESHAP). The emergency engines at the facility are subject to the requirements of 40 CFR pt. 63, subp. ZZZZ, National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines. The facility has 29 emergency generators that are subject to this standard. The facility completed the initial notification requirement for existing sources subject to 40 CFR pt. 63, subp. ZZZZ on 11/4/2005. The facility is a major source under NESHAP; therefore, existing boilers will be subject to 40 CFR pt. 63, subp. DDDDD, National Emission Standards for Hazardous Air Pollutants for Industrial, Commercial, and Institutional Boilers and Process Heaters. The requirements from this standard have been added to this permit. The compliance date for all existing emission units is January 31, 2016. The facility does not have to comply with these requirements until the compliance date. The facility completed the initial notification requirement for existing sources subject to 40 CFR pt. 63, subp. DDDDD on 5/20/2013. Best Available Retrofit Technology (BART) In 2005, 3M – Administrative Offices – Maplewood was identified as a potentially BART‐eligible facility. In April of 2005, it was determined that Boilers No. 4 and 5 (EU004 and EU005) are less than 250 MMBtu/hr and therefore not BART‐eligible. Compliance Assurance Monitoring (CAM) CAM does not apply to the emergency generators allowed in this permit amendment, since the emission units added are not large pollutant specific emission units (PSEUs) or other PSEUs. CAM does not apply to the other units at the facility because the emissions are not controlled by add‐on control equipment. Environmental Review & Air Emissions Risk Analysis (AERA) The proposed project does not require environmental review or AERA. Minnesota State Rules The proposed project is subject to the following Minnesota Standards of Performance:

Minn. R. 7011.0510 Standards of Performance for Existing Indirect Heating Equipment

Minn. R. 7011.0515 Standards of Performance for New Indirect Heating Equipment

Minn. R. 7011.1505 Standards of Performance for Storage Vessels

Minn. R. 7011.2300 Standards of Performance for Stationary Internal Combustion Engines


Table 5. Regulatory Overview of Units Affected by the Modification/Permit Amendment Subject Item* Applicable Regulations Rationale

GP001 (Existing, SI, ≤ 500 Hp, Emergency Engines)

40 CFR pt. 63, subp. ZZZZ National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines. Determination of applicable requirements from the rule:

the engines were manufactured before June 12, 2006;

the engines are emergency engines;

the engine capacities are less than 500 Hp;

the facility is a major source under 40 CFR pt. 63;

the engines do not operate for the purposes specified in 40 CFR § 63.6640(f)(2)(ii) and (iii).

Minn. R. 7011.2300 Standards of Performance for Stationary Internal Combustion Engines. Determination of applicable requirements from the rule:

the units are stationary internal combustion engines

GP002 (Existing, CI, > 500 Hp, Emergency Engines)


the engines were manufactured after December 19, 2002;


the engine capacities are greater than 500 Hp;


the engines do not operate or enter into a contract to operate more than 15 hours per calendar year for the purposes specified in 40 CFR § 63.6640(f)(2)(ii) and (iii).

***As long as the units in GP002 do not operate or enter into a contract to operate for the purposes specified in 40 CFR § 63.6640(f)(2)(ii) and (iii) for more than 15 hours per year, these units are not subject to the requirements of 40 CFR pt. 63, subps. A and ZZZZ.



GP003 (Existing, CI, ≤ 500 Hp, Emergency Engines)


the engines were manufactured before June 12, 2006;


the engine capacities are less than 500 Hp;


the engines do not operate for the purposes specified in 40 CFR § 63.6640(f)(2)(ii) and (iii).

Minn. R. 7011.2300 Standards of Performance for Stationary Internal Combustion Engines. Determination of applicable limits from rule:



Subject Item* Applicable Regulations Rationale

GP004 (New, CI > 500 Hp, Emergency Engines)




the engine capacities are greater than 500 Hp;

the facility is a major source under 40 CFR pt. 63; the engines do not operate more than 15 hours per calendar year for the purposes specified in 40 CFR § 63.6640(f)(2)(ii) and (iii).



GP005 (New, CI ≤ 500 Hp, Emergency Engines)




the engine capacities are less than or equal to 500 Hp;




EU003 (Boiler 3)

Minn. R. 7011.0510 Standards of Performance for Indirect Heating Equipment. Determination of applicable requirements from the rule:

the unit was constructed before January 31, 1977

the facility is located within the Minneapolis‐St. Paul Air Quality Control Region

the rated heat input of the unit is less than 250 MMBtu/hr

the rated heat input of all direct and indirect heating units at the facility is greater than 250 MMBtu/hr

40 CFR pt. 63, subp. DDDDD National Emissions Standards for Hazardous Air Pollutants for Industrial, Commercial and Institutional Boilers and Process Heaters. Determination of applicable requirements from the rule:

the facility is a major source of HAP emissions

the unit is existing

the facility submitted a notification that showed the intent to operate this unit such that it meets the definition of ‘unit designed to burn gas 1’

EU004 (Boiler 4)












EU005 (Boiler 5)










EU006 (Boiler 6)

Title I Limits to avoid major modification under 40 CFR §52.21 and Minn. R. 7007.3000

Limits on fuel usage, fuel sulfur content, and NOx, PM10 and PM emissions to avoid the major modification requirements of PSD.

40 CFR pt. 60, subp. Db Standards of Performance for Industrial‐Commercial‐Institutional Steam Generating Units. Determination of applicable requirements from the rule:

the unit was constructed after June 19, 1984

the rated heat capacity of the unit is greater than 100 MMBtu/hr

the allowable fuels are natural gas and fuel oil No. 2





Beginning January 31, 2016, this unit will be limited to 48 hours of operation per year while combusting fuel oil no. 2 except during periods of gas curtailment or gas supply interruptions



EU043 (Boiler 7)

Title I Limits to avoid major modification under 40 CFR §52.21 and Minn. R. 7007.3000

Limits on fuel usage, fuel sulfur content, and NOx, PM10 and PM emissions to avoid the major modification requirements of PSD. The facility can demonstrate that the emissions resulting from this modification remain below the major modification thresholds by limiting fuel usage and using CEMS and 365‐day rolling sums of emissions.

40 CFR pt. 60, subp. Db Standards of Performance for Industrial‐Commercial‐Institutional Steam Generating Units. Determination of applicable requirements from the rule:

the unit was constructed after June 19, 1984

the rated heat capacity of the unit is greater than 100 MMBtu/hr

the allowable fuels are natural gas and fuel oil No. 2





Beginning January 31, 2016, this unit will be limited to 48 hours of operation per year while combusting fuel oil no. 2 except during periods of gas curtailment or gas supply interruptions

EU044 (NG Boiler 278)


the unit was constructed after January 31, 1977




the allowable fuel is natural gas





























EU048 40 CFR pt. 60, subp. IIII Standards of Performance for Stationary Compression Ignition Internal Combustion Engines. Determination of applicable requirements from the rule:

the unit is a model year 2007 emergency stationary CI ICE with a displacement of less than 30 liters per cylinder

the unit has a max capacity of 250 kW

the unit is not a fire pump




the unit is not a fire pump



EU050 40 CFR pt. 60, subp. JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines. Determination of applicable requirements from the rule:

the unit is a model year 2009 emergency stationary SI ICE with a displacement of less than 30 liters per cylinder


the unit burns natural gas




the unit is not a fire pump ***As long as EU051 does not operate or enter into a contract to operate for the purposes specified in 40 CFR § 63.6640(f)(2)(ii) and (iii) for more than 15 hours per year, EU048 is not subject to the requirements of 40 CFR pt. 63, subps. A and ZZZZ. See 40 CFR §63.6590(b)(1).


the unit is an emergency stationary SI ICE that was manufactured before January 1, 2009; therefore the NSPS for spark ignition ICE does not apply (see 40 CFR §60.4230(a)(4)(iv).)


the unit is a model year 2009 emergency stationary SI ICE

the unit has a max capacity of 166 Hp

the unit burns natural gas











TK002 (Gasoline – unleaded)

Minn. R. 7011.1505 Standards of Performance for Storage Vessels. Determination of applicable requirements from the rule:

the tank was constructed after June 11, 1973

the capacity of the tank is less than 40,000 gallons

TK003 (Gasoline –unleaded)



the capacity of the tank is less than 40,000 gallons

TK006 (No. 2 Low Sulfur Fuel Oil)

40 CFR pt. 60, subp. Kb Standards of Performance for Volatile Organic Liquid Storage Vessels for which Construction, Reconstruction, or Modification Commenced after July 23, 1984. Determination of applicable requirements from the rule:

the capacity of the tank is less than 75m3



the capacity of the tank is greater than 40,000 gallons




the capacity of the tank is greater than 40,000 gallons

*Location of the requirement in the permit (e.g., EU, SV, GP, etc.).

3. Technical Information 3.1 Emissions Increase Analysis Criteria pollutant and HAPs emissions from the proposed emergency generator (EU055) were calculated based on NSPS subp. IIII limits and emission factors from AP‐42 Chapter 3.4: Large Stationary Diesel and All Stationary Dual‐fuel Engines, Tables 3.4‐1, 3.4‐3 and 3.4‐4. Greenhouse gas emissions were calculated based on emission factors from 40 CFR pt. 98 Tables C‐1 and C‐2. Attachment 1 to this TSD contains detailed calculation spreadsheets and supporting information prepared by the MPCA and the Permittee. In calculating the PTE for Title I modification applicability purposes, the Permittee assumed an annual hours of operation restriction for the emergency generator of 500 hours per year. The use of this


restriction is consistent with the Sept. 6, 1995 EPA memo entitled “Calculating Potential to Emit (PTE) for Emergency Generators”. 3.2 Potential to Emit Calculations Criteria pollutant and HAP emissions for existing engines were calculated using permit limits when applicable and emissions factors from AP‐42 Chapters 3.2 (natural gas engines) and 3.3 (diesel engines). GHG emissions were calculated using emissions factors and global warming potentials from 40 CFR pt. 98. Criteria pollutant and HAP emissions for existing boilers were calculated using permit limits when applicable and emissions factors from AP‐42 Chapters 1.3 (fuel oil) and 1.4 (natural gas). GHG emissions were calculated using emissions factors and global warming potentials from 40 CFR pt. 98. Emissions from storage tanks were calculated using the EPA TANKS 4.0.9d emissions estimation software. 3.3 Dispersion Modeling The requirement to conduct dispersion modeling was not triggered by this proposed project. Previously, 3M Center conducted modeling for PM10 because it was required by a previous permit

action. The results of the modeling are shown in Table 6 below. Several operating restrictions were

assumed when the modeling was conducted, so these have been incorporated as permit limits (limiting

operation to 3 generators at Building 243 at one time) in the draft/proposed Part 70 Reissuance permit

(see GP006). In addition, per MPCA practice, a table of the modeled parameters has been added to the

permit as an appendix. 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 and temperatures 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.

Table 6. Predicted Ambient Air Impacts for PM10 for 3M Center (Administrative Offices + R & D Facility)

Pollutant Averaging

Time

NAAQS

(g/m3)

Facility

Modeled

Impact

(g/m3)

Background

Concentration

(g/m3)

Total

Predicted

Impact

(g/m3)

Percent

of

Standard

PM10 24‐hour 150a 99.02c 36 135.02 90.0%

Annual 50b 16.03d 14 30.43 60.9% a Not to be exceeded more than five times during a five‐year period. b Never to be exceeded. c Concentration represents the high‐6th high from the one five‐year model run. d Concentration represents the highest high‐1st high from the five one‐year model runs.


The results of the modeling were compared to the NAAQS; the closer the results are to the standard, the more likely a facility will be required to remodel before making future changes that impact emissions or dispersion characteristics of modeled pollutants. For the case of 3M Center – Maplewood, the modeled PM10 emissions are 90% of the 24‐hour NAAQS; therefore the facility is required to conduct modeling for changes that require major or moderate amendments and affect any modeled parameter or emission rate. 3.4 PM2.5 Ambient Monitoring In March 2012, 3M completed refined PM10 dispersion modeling for the 3M Center – Maplewood campus. This modeling included all PM10 sources from both the Administrative Offices and R&D permits. The modeling demonstration showed compliance with the PM10 NAAQS. However, the modeled PM10 impacts are greater than both the annual and 24‐hour PM2.5 NAAQS. A summary table of the 2012 modeling results and the PM2.5 NAAQS is shown below.

Table 7. 2012 PM10 Modeling Results vs. PM2.5 Standards

Pollutant Parameter

24‐hour

Averaging Time

(µg/m3)

Annual

Averaging Time

(µg/m3)

PM10

2012 Background Concentrations 36 14

2012 Impacts (not including background) 99 16

2012 Impacts (including background) 135 30

PM2.5 NAAQS 35 12

Due to the modeled PM10 impacts being greater than the PM2.5 NAAQS, the MPCA requested that 3M conduct PM2.5 modeling for the entire 3M Center in Maplewood. The purpose of the PM2.5 dispersion modeling demonstration would be to identify any potential NAAQS compliance issues and, if necessary, to set 24‐hour and/or annual PM2.5 emission rates that would become legally enforceable conditions. During their review of the draft permit before public notice, 3M proposed to monitor ambient PM2.5 concentrations at the 3M Center – Maplewood campus instead of conduct PM2.5 dispersion modeling. The MPCA agrees to allow 3M to conduct PM2.5 monitoring in the place of PM2.5 modeling as long as EPA standards for monitoring are met and that the data from the monitoring are able to be compared to PM2.5 24‐hour and annual NAAQS. The goal of the monitoring is to demonstrate compliance with the PM2.5 24‐hour and annual NAAQS. Additionally, the MPCA is requiring 3M to record operational information for emission units at 3M Center – Maplewood (i.e. permits 1230015 and 12300694) that emit PM2.5 at the 3M Center such that the facility operations are able to be correlated to ambient concentrations. The purpose of the recordkeeping is to have data to inform decisions about the length of the PM2.5 monitoring exercise and to support changes made at the facility. Not all PM2.5 emitting emission units included in the permits for 3M Center (listed in permits 1230015 and 12300694) are subject to the recordkeeping requirement. The miscellaneous laboratory sources, the machine shops (EU 009) and the carpentry shops (EU 010) are excluded from the recordkeeping requirement because these units are not expected to have noticeable impacts on ambient PM2.5 concentrations due to their low PM2.5 emissions.


The MPCA expects for 3M to conduct PM2.5 monitoring until at least 3 years of data has been collected. The MPCA maintains the authority to require refined dispersion modeling when existing modeling or monitoring indicates a potential threat to the NAAQS. 3.5 Engine Best Management Practices (BMPs) This permit establishes engine BMPs that 3M has agreed to for the operation of emergency engines in an effort to protect the National Ambient Air Quality Standards. In return, the MPCA will not require 3M to include emissions from emergency engines in future dispersion modeling exercises per the current modeling guidance (MPCA Air Dispersion Modeling Guidance, July 2014). Emissions from emergency generators produce local and regional impacts on ambient air quality. The MPCA believes that by following the engine BMPs, 3M can reduce ambient impacts both locally and regionally. 3M has agreed to follow the following engine BMPs for existing and new engines:

Operate engines on ultra‐low sulfur diesel fuel. Diesel fuel with a sulfur content limited to 15 ppm is available and required to be used for the compression ignition emergency generators. Spark ignition engines operate on natural gas which is also a low sulfur fuel. The lower the sulfur in the fuel, the lower the emissions of sulfur dioxide to the atmosphere.

Vent the emissions upward without obstructions. Obstructions such as rain caps reduce dispersion and increase ambient air impacts.

Make engine test runs as short as allowed by insurance and building code considerations. The amount of pollution released is proportional to the time of operation, so limiting the duration of testing minimizes the pollutant emissions. The MPCA expects that all testing will be one hour or less for each engine.

Test engines sequentially, not at the same time. Operating multiple engines at the same time leads to higher ambient impacts.

Defer testing if the Air Quality Index (AQI) or the forecasted AQI exceeds 90 unless the test cannot be deferred. Curbing emissions during episodes during which poor air quality (indicated by a high AQI) is anticipated will help the region avoid serious air pollution problems. Because testing is not required on an exact date, it is possible to defer testing to periods of better air quality in most circumstances. The AQI and forecasted AQI can be found at: http://www.pca.state.mn.us/index.php/air/air‐quality‐and‐pollutants/general‐air‐quality/air‐quality‐index/current‐air‐quality‐index.html

In the PM10 modeling exercise conducted previously, 3M included emissions from the diesel emergency engines and modeled those emissions at 8760 hours/year. The results from the modeling indicate that the PM10 24‐hour and annual NAAQS are met. By following the engine BMPs, 3M will operate the engines less frequently than the scenario at which they were modeled. Previously, the MPCA conducted preliminary SO2 modeling for EPA State Implementation Plan purposes. The results of that modeling indicate that the 3M Center in Maplewood is in compliance with the SO2 NAAQS. The engines were included in this modeling exercise as well. As a result of this modeling, 3M is no longer permitted to use fuel oil #6 and now is only allowed fuel oil #2 in the boilers and is restricted to lower sulfur diesel fuel (from 0.5% to 0.0015% sulfur content) in the diesel engines. 3.6 Monitoring


In accordance with the Clean Air Act, it is the responsibility of the owner or operator of a facility to have sufficient knowledge of the facility to certify that the facility is in compliance with all applicable requirements. In evaluating the monitoring included in the permit, the MPCA 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. The table below summarizes the monitoring requirements associated with this amendment.

Table 6. Monitoring Subject Item*

Requirement (rule basis) Monitoring Discussion

FC PM2.5 Monitoring in order to show compliance with PM2.5 NAAQS (40 CFR pt. 50; 40 CFR pt. 58; Minn. Stat. Sec. 116.07, subds. 4a and 9)

Monitoring: 3M is required to conduct PM2.5 ambient monitoring at the 3M Center – Maplewood campus in order to demonstrate compliance with the 24‐hour and annual NAAQS for PM2.5

During facility review of the draft permit, 3M proposed to conduct PM2.5 ambient monitoring in lieu of conducting PM2.5 dispersion modeling. The MPCA has agreed to the monitoring proposal for the following reasons: the monitoring will conform to EPA reference methods, the difficulty in obtaining representative PM2.5 emission rates for many of the emission units at the facility, and the manner in which the emission units are operated.

FC Minn. R. 7007.0800, subps. 2, 4 and 5

Recordkeeping: The Permittee is required to maintain a list of all the emergency engines onsite and include the information needed to determine the applicable NSPS and NESHAP requirements in the list.

During the process of writing this permit, it was discovered that a number of emergency engines were replaced, but records of the replacement units were not clear. Additionally, information provided to the MPCA regarding the size and type of the engine of the new engines was contradictory. Therefore, the facility is required to maintain records for all emergency engines onsite to prevent future confusion.

GP001 (Existing, SI, ≤ 500 Hp, Emergency Engines)

Opacity ≤ 20% once operating temperatures have been attained; SO2 ≤ 0.5 lb/MMBtu heat input (Minn. R. 7011.2300)

None. All units use natural gas only, by design; therefore the likelihood of violating either of the emission limits is very small. The Permittee can demonstrate that these units will continue to operate such that emissions are well below the emission limits by only burning natural gas.


Subject Item*


Change oil filter every 500 hours; Inspect spark plugs every 1,000 hours; Inspect hoses and belts every 500 hours Hours of operation ≤ 100 hr/yr for the purposes of 63.6640(f)(2); ≤ 50 hr/yr for the purposes of 63.6640(f)(3) (40 CFR pt. 63, subp. ZZZZ)

Recordkeeping: The Permittee is required to keep records of the maintenance conducted on the stationary RICE. Recordkeeping: The Permittee is required to install and operate a non‐resettable hour meter on each engine and use the hour meter to record the number of hours of operation for each purpose.

The recordkeeping required by the NESHAP is sufficient to demonstrate compliance with the work practice standards. The recordkeeping required by the NESHAP is sufficient to demonstrate compliance with the hours of operation limits.

GP002 (Existing, CI, > 500 Hp, Emergency Engines)


None. All units use low sulfur diesel only, by design; therefore the likelihood of violating either of the emission limits is very small. The Permittee can demonstrate that these units will continue to operate such that emissions are well below the emission limits by only burning low sulfur diesel fuel.

GP003 (Existing, CI, ≤ 500 Hp, Emergency Engines)


None. All units use low sulfur diesel only, by design; therefore the likelihood of violating either of the emission limits is very small. The Permittee can demonstrate that these units will continue to operate such that emissions are well below the emission limits by only burning low sulfur diesel fuel.


Subject Item*


Change oil filter every 500 hours; Inspect air cleaner every 1,000 hours; Inspect hoses and belts every 500 hours Hours of operation ≤ 100 hr/yr for the purposes of 63.6640(f)(2); ≤ 50 hr/yr for the purposes of 63.6640(f)(3) (40 CFR pt. 63, subp. ZZZZ)

Recordkeeping: The Permittee is required to keep records of the maintenance conducted on the stationary RICE. Recordkeeping: The Permittee is required to install and operate a non‐resettable hour meter on each engine and use the hour meter to record the number of hours of operation for each purpose.

The recordkeeping required by the NESHAP is sufficient to demonstrate compliance with the work practice standards. The recordkeeping required by the NESHAP is sufficient to demonstrate compliance with the hours of operation limits.

GP004 (New, CI, >500 Hp, Emergency Engines)

SO2 ≤ 0.50 lb/MMBtu heat input; Opacity ≤ 20 % once operating temperatures attained (Minn. R. 7011.2300)

Recordkeeping: fuel type and usage records generated on a monthly basis.

This unit is required to operate using ultra‐low sulfur diesel fuel (less than 15 ppm sulfur) by the NSPS. Based on the fuel type, the likelihood of violating either limit is very small. Records showing that only ultra‐low sulfur diesel is combusted in this unit is sufficient to demonstrate compliance with these limits.

Hours of operation ≤ 500 hours per year (Minn. R. 7007.0800)

Recordkeeping: hours of operation based on non‐resettable hour meter

The Permittee is required by applicable NSPS requirements to install a non‐resettable hour meter. This limit is required as part of the definition of an emergency generator per the Sept. 6, 1995 EPA entitled “Calculating Potential to Emit (PTE) for Emergency Generators”.

GP005 (New, CI ≤ 500 Hp, Emergency Engines)

SO2 ≤ 0.50 lb/MMBtu heat input; Opacity ≤ 20 % once operating temperatures attained (Minn. R. 7011.2300)

Recordkeeping: fuel type and usage records generated on a monthly basis.

This unit is required to operate using ultra‐low sulfur diesel fuel (less than 15 ppm sulfur) by the NSPS. Based on the fuel type, the likelihood of violating either limit is very small. Records showing that only ultra‐low sulfur diesel is combusted in this unit is sufficient to demonstrate compliance with these limits.

EU003 (Boiler 3)

Sulfur content of fuel ≤ 0.05%; Opacity ≤ 20% with exceptions (Minn. R. 7011.0510)

Monitoring: Daily visible emission checks. Recordkeeping: fuel type records.

This unit is required to operate using low sulfur diesel fuel (0.05% sulfur content). Based on the fuel type, the likelihood of violating either limit is very small. Monitoring of visible emissions and records showing that only low sulfur diesel is combusted in this unit is sufficient to demonstrate compliance with these limits.


Subject Item*


EU004 (Boiler 4)




EU005 (Boiler 5)




EU006 (Boiler 6)

Fuel usage ≤ 1,090,000 gallons/year; Fuel usage ≤ 31,000 gallons/day; Natural gas and No. 2 fuel oil usage ≤ 91,324 MMBtu/month; Fuel sulfur content ≤ 0.5% by weight for No. 2 fuel oil; NOx ≤ 0.067 lbs/MMBtu for natural gas; NOx ≤ 0.10 lbs/MMBtu for No. 2 fuel oil; PM and PM10 ≤ 0.021 lbs/MMBtu; (Title I limits to avoid major modification)

Monitoring: CEMS for NOx, O2; COMS for opacity; 30‐day NOx performance test (upon request by MPCA). Recordkeeping: fuel supplier certification that fuel oil No. 2 is less than 0.5%.

This unit is subject to 40 CFR pt. 60, subp. Db which requires CEMS and COMS. These monitors are sufficient for determining compliance with the Title I limits as well as the NSPS limits. Fuel usage records are sufficient for determining compliance with the fuel usage limits. Note: limits taken for avoiding modeling further restrict fuel sulfur content to less than 0.05%. Compliance with PM and PM10 limits is demonstrated by burning natural gas (0.0075 lb/MMBtu) and No. 2 fuel oil (0.017 lb/MMBtu) only.


Subject Item*


Fuel sulfur content ≤ 0.5% by weight for No. 2 fuel oil; SO2 ≤ 0.20 lb/MMBtu using 30‐day rolling average; NOx ≤ 0.10 lb/MMBtu using 30‐day rolling average at the low release rate; NOx ≤ 0.20 lb/MMBtu using 30‐day rolling average at the high release rate Opacity ≤ 20% with exceptions (40 CFR pt. 60, subp. Db)


This unit is subject to 40 CFR pt. 60, subp. Db which requires CEMS and COMS. Fuel usage records are sufficient for determining compliance with the fuel usage limits. Note: limits taken for avoiding modeling restrict fuel sulfur content to less than 0.05%.

Fuel sulfur content ≤ 0.05 %; (Minn. Stat. Section 116.07, subds. 4a & 9)

Recordkeeping: fuel supplier certification that fuel oil No. 2 is less than 0.05%.

Fuel usage records are sufficient for determining compliance with the fuel usage limits.

EU043 (Boiler 7)

NOx ≤ 39.0 tons/year; SO2 ≤ 38.0 tons/year; PM10 ≤ 13.0 tons/year; Fuel usage ≤ 10,000,000 gallons/year of No. 2 fuel oil; Fuel sulfur content ≤ 0.5 %; NOx ≤ 0.20 lbs/MMBtu; Opacity ≤ 20% with exceptions


This unit is subject to 40 CFR pt. 60, subp. Db which requires CEMS and COMS. These monitors are sufficient for determining compliance with the Title I limits as well as the NSPS limits. Fuel usage records are sufficient for determining compliance with the fuel usage limits. Note: limits taken for avoiding modeling restrict fuel sulfur content to less than 0.05%.


Subject Item*


SO2 ≤ 0.20 lb/MMBtu using 30‐day rolling average; Fuel sulfur content ≤ 0.5 %; NOx ≤ 0.20 lbs/MMBtu using 30‐day rolling average; Opacity ≤ 20% with exceptions (40 CFR pt. 60, subp. Db)


This unit is subject to 40 CFR pt. 60, subp. Db which requires CEMS and COMS. Fuel usage records are sufficient for determining compliance with the fuel usage limits. Note: limits taken for avoiding modeling restrict fuel sulfur content to less than 0.05%.

Fuel sulfur content ≤ 0.05 %; (Minn. Stat. Section 116.07, subds. 4a & 9)

Recordkeeping: fuel supplier certification that fuel oil No. 2 is less than 0.05%.

Fuel usage records are sufficient for determining compliance with the fuel usage limits.


PM ≤ 0.4 lbs/MMBtu heat input; Opacity ≤ 20% with exceptions (Minn. R. 7011.0515)

None. This unit uses natural gas only, by design. Based on the fuel type, the likelihood of violating either limit is very small. The Permittee can demonstrate that this unit will continue to operate such that emissions are well below the emission limits by only burning natural gas.







EU048 PM ≤ 0.20 g/kW‐hr; NMHC+NOx ≤ 4.0 g/kW‐hr; CO ≤ 3.50 g/kW‐hr (40 CFR pt. 60, subp. IIII)

None. The manufacturer is required to certify that the engine will meet these emission limits for the life of the engine. No further monitoring or recordkeeping is required by the NSPS.


Subject Item*




EU050 NOx + HC ≤ 4.0 g/kW‐hr; PM ≤ 0.30 g/kW‐hr (40 CFR pt. 60, subp. IIII)




EU053 NOx ≤ 4.0 g/kW‐hr or ≤ 160 ppm, volumetric, dry at 15% O2; CO ≤ 4.0 g/kW‐hr or ≤ 540 ppm, volumetric, dry at 15% O2 VOC ≤ 1.0 g/kW‐hr or ≤ 86 ppm, volumetric, dry at 15% O2 (40 CFR pt. 60, subp. JJJJ)





Subject Item*




CE003 (Diesel Particulate Filter)

PM, PM10, PM2.5 ≥ 85.0% control efficiency; CO ≥ 90.0% control efficiency (Minn. R. 7007.0800)

Monitoring: During each period of operation of EU055, check the back pressure alarm. Recordkeeping: Generate and maintain records of corrective actions taken.

This control device is equipped with a back pressure alarm that signals if the high back pressure limit of the engine is approached. The Permittee is required to generate and maintain records of any corrective actions taken due to the back pressure alarm.

TK002 (Gasoline – unleaded) TK003 (Gasoline –unleaded)

Equip storage vessel with a permanent submerged fill pipe or comply with Minn. R. 7011.1505, subp. 3(C) (Minn. R. 7011.1505)

None. This requirement is a design requirement with no relevant monitoring.


Equip storage vessel with a permanent submerged fill pipe or comply with Minn. R. 7011.1505, subp. 3(C) (Minn. R. 7011.1505)


Maintain records showing tank dimensions (40 CFR pt. 60, subp. Kb)

None. This requirement is a recordkeeping requirement with no relevant monitoring.


Subject Item*



Equip the storage vessel with a floating roof, a vapor recovery system or equivalent based on true vapor pressure (Minn. R. 7011.1505)


*Location of the requirement in the permit (e.g., EU, SV, GP, etc.).

3.7 Insignificant Activities The 3M – Administrative Offices – Maplewood facility has cooling towers that are classified as insignificant activities under the MPCA’s permitting rules. These are listed in Appendix II 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 7. Insignificant Activities

Insignificant Activity General Applicable

Emission limit Discussion

Individual units with potential emissions less than 2000 lb/year of certain pollutants

PM, variable depending on airflow Opacity ≤ 20% (with exceptions) (Minn. R. 7011.0715)

These are cooling towers. Potential emissions of PM are low compared to what is allowed by the rule. Noncompliance is unlikely.

3.8 Permit Organization In general, the permit meets the MPCA Delta Guidance for ordering and grouping of requirements. One area that deviates from the guidance is the use of groups where the requirements in the group apply to the members of the group individually. This was done in order to shorten the permit and where no testing or tracking specific to a unit is in the permit (thereby reducing the likelihood that there where will be further unit‐specific requirements later). This is the case for the requirements at GP001 (Existing, SI ≤ 500, Hp, Emergency Engines), GP002 (Existing, CI > 500 Hp, Emergency Engines), GP003 (Existing, CI ≤ 500 Hp, Emergency Engines), GP004 (New, CI > 500 Hp, Emergency Engines), GP005 (New, CI, ≤ 500 Hp, Emergency Engines, GP006 (Building 243 Engines) and GP011 (Best Management Practices for Emergency Engines.


Another area that deviates from the guidance is in the use of groups for calculating emissions for listing in the facility description in Delta. This is the case for GP007 (Natural Gas Emergency Generators), GP008 (Diesel Generators < 600 Hp), GP009 (Diesel Generators > 600 Hp, and GP010 (Bldg 278 NG Boilers). 3.9 Comments Received This section will be completed after the reference review periods. Public Notice Period: <start date> ‐ <end date> EPA 45‐day Review Period: <start date> ‐ <end date> 4. Permit Fee Assessment Attachment 3 to this TSD contains the MPCA’s assessment of Application and Additional Points used to determine the permit application fee for this permit action as required by Minn. R. 7002.0019. The action includes the incorporation of NSPS and NESHAP requirements for a new emergency generator (EU055); fees apply to these changes. The action includes four additional amendment applications; only two were received after the effective date of the fee rule (July 1, 2009). NSPS requirements for EU048‐EU054 were included as result of these applications; fees apply to these changes. The permit action also includes the incorporation of NESHAP requirements for 28 existing generators, however this was an existing standard that applied to the facility and is not a chargeable activity (i.e., the standard was not triggered by the changes requested in the permit applications – it falls under a permit reopening but is being rolled into this permit action). 5. Conclusion Based on the information provided by 3M Company, the MPCA has reasonable assurance that the proposed operation of the emission facility, as described in the Air Emission Permit No. 12300694‐004 and this TSD, will not cause or contribute to a violation of applicable federal regulations and Minnesota Rules. Staff Members on Permit Team: Cindy Schafer (permit engineer)

Steve Palzkill (enforcement) Brent Rohne (enforcement) Curtis Stock (compliance) Bonnie Nelson (peer reviewer) Beckie Olson (permit writing assistant) Sandy Simbeck (administrative support)

AQ File No. 23EE; DQ 2123 (Part 70 Reissuance), DQ 4131 (major amendment), DQ 4689 (moderate amendment), DQ 2332 (minor amendment), DQ 4862 (minor amendment) DQ 3303 (administrative amendment), DQ 1231 (notification), DQ 4796 (notification), DQ 4797 (notification), and DQ 2222 (reopening). Attachments: 1. Facility Potential to Emit and Emissions Increase Calculation Spreadsheets

2. Facility Description and CD‐01 Forms 3. Points Calculator

ATTACHMENT 1 TECHNICAL SUPPORT DOCUMENT FOR PERMIT NO. 12300694

Facility Potential to Emit and Emissions Increase Calculation Spreadsheets

Emission Unit Emission

Number Source (lb/hr) (ton/yr) (lb/hr) (ton/yr) (lb/hr) (ton/yr) (lb/hr) (ton/yr) (lb/hr) (ton/yr) (lb/hr) (ton/yr) (lb/hr) (ton/yr) (lb/hr) (ton/yr) (lb/hr) (ton/yr)

003 Boiler 3 210‐B03 2.97 12.99 2.07 9.05 1.39 6.10 34.04 149.09 6.38 27.94 10.21 44.73 0.67 2.93 0.26 1.15 20245.52 88675

004 Boiler 4 210‐B04 4.40 19.27 3.07 13.43 2.07 9.05 50.51 221.23 9.47 41.46 15.15 66.37 0.99 4.35 0.39 1.70 30041.75 131583

005 Boiler 5 210‐B05 4.40 19.27 3.07 13.43 2.07 9.05 50.51 221.23 9.47 41.46 15.15 66.37 0.99 4.35 0.39 1.70 30041.75 131583

006 Boiler 6 210‐B06 5.24 7.15 3.65 7.15 2.46 7.15 40.79 178.68 11.27 3.87 18.04 78.99 1.18 5.17 0.46 1.78 35756.21 112087

008 NG Generator 201‐731417 0.05 0.01 0.05 0.01 0.05 0.01 3.42 0.86 0.00 0.00 0.42 0.10 0.13 0.03 0.09 0.02 126.09 32

009 NG Generator 205‐821913 0.04 0.01 0.04 0.01 0.04 0.01 2.38 0.59 0.00 0.00 0.29 0.07 0.09 0.02 0.06 0.01 87.72 22

010 NG Generator 209‐734566 0.02 0.00 0.02 0.00 0.02 0.00 1.19 0.30 0.00 0.00 0.14 0.04 0.05 0.01 0.03 0.01 43.86 11

016 NG Generator 230‐427957 0.08 0.02 0.08 0.02 0.08 0.02 5.21 1.30 0.00 0.00 0.63 0.16 0.20 0.05 0.13 0.03 191.88 48

018 NG Generator 235‐EG0001 0.07 0.02 0.07 0.02 0.07 0.02 4.85 1.21 0.00 0.00 0.59 0.15 0.18 0.05 0.12 0.03 178.72 45

021 NG Generator 236‐EG0001 0.08 0.02 0.08 0.02 0.08 0.02 5.35 1.34 0.00 0.00 0.65 0.16 0.20 0.05 0.13 0.03 197.36 49

025 Diesel Generator 223‐427829 0.91 0.23 0.91 0.23 0.91 0.23 12.91 3.23 0.85 0.21 2.78 0.70 1.05 0.26 0.01 0.00 477.99 119


028 Diesel Generator 277‐EG0001 0.52 0.13 0.43 0.11 0.42 0.10 24.02 6.01 3.79 0.95 6.38 1.60 0.61 0.15 0.00 0.00 1225.62 306




032 Diesel Generator 5 243‐512084 0.39 0.10 0.32 0.08 0.31 0.08 18.02 4.50 2.84 0.71 4.79 1.20 0.46 0.12 0.00 0.00 919.22 230









043 Boiler 7 5.24 16.50 3.65 11.50 2.46 7.75 40.79 39.00 11.27 35.50 18.04 78.99 1.18 5.17 0.46 1.93 35756.21 112657

044 NG Boiler 278 0.04 0.20 0.04 0.20 0.04 0.20 0.59 2.58 0.00 0.02 0.49 2.16 0.03 0.14 0.00 0.02 701.12 3071

045 NG Boiler 278 0.04 0.20 0.04 0.20 0.04 0.20 0.59 2.58 0.00 0.02 0.49 2.16 0.03 0.14 0.00 0.02 701.12 3071

046 NG Boiler 278 0.04 0.20 0.04 0.20 0.04 0.20 0.59 2.58 0.00 0.02 0.49 2.16 0.03 0.14 0.00 0.02 701.12 3071

047 Diesel Generator 278 0.08 0.02 0.08 0.02 0.08 0.02 1.13 0.28 0.07 0.02 0.24 0.06 0.09 0.02 0.00 0.00 41.80 10



050 Fire Pump 217‐00001 0.35 0.09 0.35 0.09 0.35 0.09 4.92 1.23 0.32 0.08 1.06 0.27 0.40 0.10 0.00 0.00 182.31 46


052 NG Generator 216‐168605 0.06 0.01 0.06 0.01 0.057 0.01 3.72 0.93 0.00 0.00 0.45 0.11 0.14 0.04 0.09 0.02 137.06 34

053 NG Generator 218‐321528 0.06 0.01 0.06 0.01 0.057 0.01 3.72 0.93 0.00 0.00 0.45 0.11 0.14 0.04 0.09 0.02 137.06 34



TK002 Gasoline Tank 1.96E‐01 0.86

TK003 Gasoline Tank 2.92E‐01 1.28

TK006 No. 6 Fuel Oil Tank 5.94E‐05 2.60E‐04

TK007 No. 2 Fuel Oil Tank 6.20E‐03 0.03

Total Emissions 33.6 78.6 26.0 57.7 20.8 42.2 565.8 903.8 89.1 160.6 164.1 363.4 20.1 28.2 2.8 8.5 171608.2 590213.5

(lb/hr) (ton/yr) (lb/hr) (ton/yr) (lb/hr) (ton/yr) (lb/hr) (ton/yr) (lb/hr) (ton/yr) (lb/hr) (ton/yr) (lb/hr) (ton/yr) (lb/hr) (ton/yr) (lb/hr) (ton/yr)

Total HAPs 2 GHG (CO2e)PM PM10 PM2.5 NOX SO2 CO VOC

H:\3M Admin Offices Maplewood\App\3M Center Admin PTE Calcs - 07 14 14.xlsx 1of 29

Boiler 3 (EU 003)

Design Heat Input 124 MMBtu/hr

Fuel Type Heat Value1 Fuel

Consumption

Rate

Maximum Sulfur

Content2

Natural Gas 1,020 Btu/scf 0.122 MMscf/hr NA

No. 2 Fuel Oil 138 MMBtu/kgal 0.90 kgal/hr 0.05

PollutantEmission Factor3

(lb/MMscf)

Emission Rate

(lbs/hr)

Potential Emissions

(tons/yr)

Emission

Factor4

(lb/kgal)

Emission Rate

(lbs/hr)

Potential

Emissions

(tons/yr)

Emission Rate

(lbs/hr)

Potential

Emissions

(tons/yr)

PM 7.60 0.92 4.05 3.3 2.97 12.99 2.97 12.99

PM10 7.60 0.92 4.05 2.3 2.07 9.05 2.07 9.05

PM2.5 7.60 0.92 4.05 1.6 1.39 6.10 1.39 6.10

NOx 280 34.04 149.09 24 21.57 94.46 34.04 149.09

SO2 0.6 0.07 0.32 7.1 6.38 27.94 6.38 27.94

CO 84 10.21 44.73 5 4.49 19.68 10.21 44.73

VOC 5.50 0.67 2.93 0.2 0.18 0.79 0.67 2.93

Lead 0.0005 0.00006 0.0003 NA ‐‐ ‐‐ 0.00006 0.0003

CO25

119,067 14,475 63,399 22,454 20,176 88,372 20,176 88,372

CH45

2.2 0.27 1.19 0.91 0.82 3.58 0.82 3.58

N2O5

0.22 0.03 0.12 0.18 0.16 0.72 0.16 0.72

CO2e6

119,190 14,490 63,465 ‐‐ 20,246 88,675 20,246 88,675

1 Heat values for 40 CFR Part 98, Table C‐1.2 Maximum permitted sulfur content of No. 2 Fuel Oil. 3 Emission factors from AP‐42, Section 1.4 (07/98).4 Emission factors from AP‐42, Section 1.3 (05/10). PM, PM10 and PM2.5 emission factors are are the sum of condensibles from

Table 1.3‐2 and filterable from Table 1.3‐6. The VOC emission factor is obtained from table 1.3‐3.5 CO2, CH4 and N2O emission factors converted from Tables C‐1 and C‐2 to Subpart C of Part 986 CO2e is the sum of CO2, CH4 and N2O emissions times their respective global warming potential as listed in Table A‐1 to Subpart A of Part 98

Natural Gas No. 2 Fuel Oil Worst‐Case Emissions

Boiler 3 (EU 003)



Consumption

Rate

Maximum Sulfur

Content2


No. 2 Fuel Oil 138 MMBtu/kgal 0.90 kgal/hr 0.5%


(lb/MMscf)

Emission Rate

(lbs/hr)

Potential Emissions

(tons/yr)

Emission

Factor4

(lb/kgal)

Emission Rate

(lbs/hr)

Potential

Emissions

(tons/yr)

Emission Rate

(lbs/hr)

Potential

Emissions

(tons/yr)

Arsenic 2.00E‐04 2.43E‐05 1.06E‐04 5.52E‐04 4.96E‐04 2.17E‐03 4.96E‐04 2.17E‐03

Benzene 2.10E‐03 2.55E‐04 1.12E‐03 2.14E‐04 1.92E‐04 8.42E‐04 2.55E‐04 1.12E‐03

Beryllium 1.20E‐05 1.46E‐06 6.39E‐06 4.14E‐04 3.72E‐04 1.63E‐03 3.72E‐04 1.63E‐03

Cadmium 1.10E‐03 1.34E‐04 5.86E‐04 4.14E‐04 3.72E‐04 1.63E‐03 3.72E‐04 1.63E‐03

Chromium 1.40E‐03 1.70E‐04 7.45E‐04 4.14E‐04 3.72E‐04 1.63E‐03 3.72E‐04 1.63E‐03

Cobalt 8.40E‐05 1.02E‐05 4.47E‐05 ‐‐‐ ‐‐‐ ‐‐‐ 1.02E‐05 4.47E‐05

Dichlorobenzene 1.20E‐03 1.46E‐04 6.39E‐04 ‐‐‐ ‐‐‐ ‐‐‐ 1.46E‐04 6.39E‐04

Ethyl Benzene ‐‐ ‐‐ ‐‐ 6.36E‐05 5.71E‐05 2.50E‐04 5.71E‐05 2.50E‐04

Formaldehyde 7.50E‐02 9.12E‐03 3.99E‐02 3.30E‐02 2.97E‐02 1.30E‐01 2.97E‐02 1.30E‐01

Hexane 1.80E+00 2.19E‐01 9.58E‐01 ‐‐‐ ‐‐‐ ‐‐‐ 2.19E‐01 9.58E‐01

Manganese 3.80E‐04 4.62E‐05 2.02E‐04 8.28E‐04 7.44E‐04 3.26E‐03 7.44E‐04 3.26E‐03

Mercury 2.60E‐04 3.16E‐05 1.38E‐04 4.14E‐04 3.72E‐04 1.63E‐03 3.72E‐04 1.63E‐03

Naphthalene 6.10E‐04 7.42E‐05 3.25E‐04 1.13E‐03 1.02E‐03 4.45E‐03 1.02E‐03 4.45E‐03

Nickel 2.10E‐03 2.55E‐04 1.12E‐03 4.14E‐04 3.72E‐04 1.63E‐03 3.72E‐04 1.63E‐03

POM2 6.97E‐04 8.47E‐05 3.71E‐04 1.43E‐03 1.28E‐03 5.61E‐03 1.28E‐03 5.61E‐03

Selenium 2.40E‐05 2.92E‐06 1.28E‐05 2.07E‐03 1.86E‐03 8.15E‐03 1.86E‐03 8.15E‐03

Toluene 3.40E‐03 4.13E‐04 1.81E‐03 6.20E‐03 5.57E‐03 2.44E‐02 5.57E‐03 2.44E‐02

Xylene ‐‐ ‐‐ ‐‐ 1.09E‐04 9.79E‐05 4.29E‐04 9.79E‐05 4.29E‐04

HAPs ‐ Total 2.61E‐01 1.14E+00

Total Emissions 2.62E‐01 1.15E+00

1 Heat values for 40 CFR Part 98, Table C‐1.2 Maximum permitted sulfur content of No. 2 Fuel Oil. 3 Emission factors from AP‐42, Section 1.4 (07/98).


4 Emission factors from AP‐42, Section 1.3 (05/10). Metals emission factors for As, Cd, Cr, Mn, Hg, Ni, and Se from AP‐42, Section 1.3, Table 1.3‐10 (05/10),

converted by lb/1012 Btu * 106 Btu/MMBtu * 140 MMBtu/103 gal = lb/103 gal

Boiler 4 (EU 004)



Consumption

Rate

Maximum Sulfur

Content2



PollutantEmission Factor

3

(lb/MMscf)

Emission Rate

(lbs/hr)

Potential Emissions

(tons/yr)

Emission

Factor4

(lb/kgal)

Emission Rate

(lbs/hr)

Potential

Emissions

(tons/yr)

Emission Rate

(lbs/hr)

Potential

Emissions

(tons/yr)

PM 7.60 1.37 6.00 3.3 4.40 19.27 4.40 19.27

PM10 7.60 1.37 6.00 2.3 3.07 13.43 3.07 13.43

PM2.5 7.60 1.37 6.00 1.6 2.07 9.05 2.07 9.05

NOx 280 50.51 221.23 24 32.00 140.16 50.51 221.23

SO2 0.6 0.11 0.47 7.1 9.47 41.46 9.47 41.46

CO 84 15.15 66.37 5 6.67 29.20 15.15 66.37

VOC 5.50 0.99 4.35 0.2 0.27 1.17 0.99 4.35

Lead 0.0005 0.00009 0.0004 NA ‐‐ ‐‐ 0.00009 0.0004

CO25

119,067 21,479 94,077 22,454 29,939 131,133 29,939 131,133

CH45

2.2 0.40 1.77 0.91 1.21 5.32 1.21 5.32

N2O5

0.22 0.04 0.18 0.18 0.24 1.06 0.24 1.06

CO2e6

119,190 21,501 94,174 ‐‐ 30,042 131,583 30,042 131,583

1 Heat values for 40 CFR Part 98, Table C‐1.

2 Maximum permitted sulfur content of No. 2 Fuel Oil. 3 Emission factors from AP‐42, Section 1.4 (07/98).4 Emission factors from AP‐42, Section 1.3 (05/10). PM, PM10 and PM2.5 emission factors are are the sum of condensibles from



Boiler 4 (EU 004)



Consumption

Rate

Maximum Sulfur

Content2




3

(lb/MMscf)

Emission Rate

(lbs/hr)

Potential Emissions

(tons/yr)

Emission

Factor4

(lb/kgal)

Emission Rate

(lbs/hr)

Potential

Emissions

(tons/yr)

Emission Rate

(lbs/hr)

Potential

Emissions

(tons/yr)






Cobalt 8.40E‐05 1.52E‐05 6.64E‐05 ‐‐‐ ‐‐‐ ‐‐‐ 1.52E‐05 6.64E‐05




Hexane 1.80E+00 3.25E‐01 1.42E+00 ‐‐‐ ‐‐‐ ‐‐‐ 3.25E‐01 1.42E+00




Nickel 2.10E‐03 3.79E‐04 1.66E‐03 4.14E‐04 5.52E‐04 2.42E‐03 5.52E‐04 2.42E‐03

POM2 6.97E‐04 1.26E‐04 5.51E‐04 1.43E‐03 1.90E‐03 8.33E‐03 1.90E‐03 8.33E‐03



Xylene ‐‐ ‐‐ ‐‐ 1.09E‐04 1.45E‐04 6.37E‐04 1.45E‐04 6.37E‐04

HAPs ‐ Total 3.87E‐01 1.70E+00



2 Maximum permitted sulfur content of No. 2 Fuel Oil. 3 Emission factors from AP‐42, Section 1.4 (07/98).

4 Emission factors from AP‐42, Section 1.3 (05/10).


Boiler 5 (EU 005)



Consumption

Rate

Maximum Sulfur

Content2




3

(lb/MMscf)

Emission Rate

(lbs/hr)

Potential Emissions

(tons/yr)

Emission

Factor4

(lb/kgal)

Emission Rate

(lbs/hr)

Potential

Emissions

(tons/yr)

Emission Rate

(lbs/hr)

Potential

Emissions

(tons/yr)

PM 7.60 1.37 6.00 3.3 4.40 19.27 4.40 19.27

PM10 7.60 1.37 6.00 2.3 3.07 13.43 3.07 13.43

PM2.5 7.60 1.37 6.00 1.6 2.07 9.05 2.07 9.05

NOx 280 50.51 221.23 24 32.00 140.16 50.51 221.23

SO2 0.6 0.11 0.47 7.1 9.47 41.46 9.47 41.46

CO 84 15.15 66.37 5 6.67 29.20 15.15 66.37

VOC 5.50 0.99 4.35 0.2 0.27 1.17 0.99 4.35

Lead 0.0005 0.00009 0.0004 NA ‐‐ ‐‐ 0.00009 0.0004

CO25

119,067 21,479 94,077 22,454 29,939 131,133 29,939 131,133

CH45

2.2 0.40 1.77 0.91 1.21 5.32 1.21 5.32

N2O5

0.22 0.04 0.18 0.18 0.24 1.06 0.24 1.06

CO2e6

119,190 21,501 94,174 ‐‐ 30,042 131,583 30,042 131,583


2 Maximum permitted sulfur content of No. 2 Fuel Oil. 3 Emission factors from AP‐42, Section 1.4 (07/98).4 Emission factors from AP‐42, Section 1.3 (05/10). PM, PM10 and PM2.5 emission factors are are the sum of condensibles from



Boiler 5 (EU 005)



Consumption

Rate

Maximum Sulfur

Content2




3

(lb/MMscf)

Emission Rate

(lbs/hr)

Potential Emissions

(tons/yr)

Emission

Factor4

(lb/kgal)

Emission Rate

(lbs/hr)

Potential

Emissions

(tons/yr)

Emission Rate

(lbs/hr)

Potential

Emissions

(tons/yr)






Cobalt 8.40E‐05 1.52E‐05 6.64E‐05 ‐‐‐ ‐‐‐ ‐‐‐ 1.52E‐05 6.64E‐05




Hexane 1.80E+00 3.25E‐01 1.42E+00 ‐‐‐ ‐‐‐ ‐‐‐ 3.25E‐01 1.42E+00




Nickel 2.10E‐03 3.79E‐04 1.66E‐03 4.14E‐04 5.52E‐04 2.42E‐03 5.52E‐04 2.42E‐03

POM2 6.97E‐04 1.26E‐04 5.51E‐04 1.43E‐03 1.90E‐03 8.33E‐03 1.90E‐03 8.33E‐03



Xylene ‐‐ ‐‐ ‐‐ 1.09E‐04 1.45E‐04 6.37E‐04 1.45E‐04 6.37E‐04



2 Maximum permitted sulfur content of No. 2 Fuel Oil. 3 Emission factors from AP‐42, Section 1.4 (07/98).

4 Emission factors from AP‐42, Section 1.3 (05/10).


Boiler 6 (EU 006)


Fuel Type Heat Value1 Fuel Consumption

Rate

Fuel Usage

Limits2Maximum

Sulfur

Content3

(percent)

Natural Gas 1,020 Btu/scf 0.215 MMscf/hr NA NA

No. 2 Fuel Oil 138 MMBtu/kgal 1.59 kgal/hr 1,090,000 gal/yr 0.05


(lb/MMscf)

Emission Rate

(lbs/hr)

Potential Emissions

(tons/yr)

Emission

Factor5

(lb/kgal)

Emission Rate

(lbs/hr)

Limited

Potential

Emissions

(tons/yr)

Emission Rate

(lbs/hr)

Potential

Emissions

(tons/yr)

PM 7.60 1.63 7.15 3.3 5.24 1.80 5.24 7.15

PM10 7.60 1.63 7.15 2.3 3.65 1.25 3.65 7.15

PM2.5 7.60 1.63 7.15 1.6 2.46 0.84 2.46 7.15

NOx 190 40.79 178.68 24 38.09 13.08 40.79 178.68

SO2 0.6 0.13 0.56 7.1 11.27 3.87 11.27 3.87

CO 84 18.04 78.99 5 7.93 2.73 18.04 78.99

VOC 5.50 1.18 5.17 0.2 0.32 0.11 1.18 5.17

Lead 0.0005 0.00011 0.0005 NA ‐‐ ‐‐ 0.00011 0.0005

CO26

119,067 25,564 111,972 22,454 35,634 12,238 35,634 111,972

CH46

2.2 0.48 2.11 0.91 1.45 0.50 1.45 2.11

N2O6

0.22 0.05 0.21 0.18 0.29 0.10 0.29 0.21

CO2e7

119,190 25,591 112,087 ‐‐ 35,756 12,280 35,756 112,087

1 Heat values for 40 CFR Part 98, Table C‐1.2 No. 2 fuel oil limited to 1,090,000 gal/year3 Maximum permitted sulfur content of No. 2 Fuel Oil. 4 Emission factors from AP‐42, Section 1.4 (07/98).5 Emission factors from AP‐42, Section 1.3 (05/10). PM, PM10 and PM2.5 emission factors are are the sum of condensibles from



Boiler 6 (EU 006)



Rate

Fuel Usage

Limits2Maximum

Sulfur

Content3


No. 2 Fuel Oil 138 MMBtu/kgal 1.59 kgal/hr 1,090,000 gal/yr 0.5%


(lb/MMscf)

Emission Rate

(lbs/hr)

Potential Emissions

(tons/yr)

Emission

Factor5

(lb/kgal)

Emission Rate

(lbs/hr)

Limited

Potential

Emissions

(tons/yr)

Emission Rate

(lbs/hr)

Potential

Emissions

(tons/yr)






Cobalt 8.40E‐05 1.80E‐05 7.90E‐05 ‐‐‐ ‐‐ ‐‐ 1.80E‐05 7.90E‐05

Dichlorobenzene 1.20E‐03 2.58E‐04 1.13E‐03 ‐‐‐ ‐‐ ‐‐ 2.58E‐04 1.13E‐03



Hexane 1.80 0.39 1.69 ‐‐‐ ‐‐ ‐‐ 0.39 1.69




Nickel 2.10E‐03 4.51E‐04 1.97E‐03 4.14E‐04 6.57E‐04 2.26E‐04 6.57E‐04 1.97E‐03

POM2 6.97E‐04 1.50E‐04 6.55E‐04 1.43E‐03 2.26E‐03 7.77E‐04 2.26E‐03 7.77E‐04



Xylene ‐‐ ‐‐ ‐‐ 1.09E‐04 1.73E‐04 5.94E‐05 1.73E‐04 5.94E‐05


1 Heat values for 40 CFR Part 98, Table C‐1.2 No. 2 fuel oil limited to 1,090,000 gal/year3 Maximum permitted sulfur content of No. 2 Fuel Oil. 4 Emission factors from AP‐42, Section 1.4 (07/98).5 Emission factors from AP‐42, Section 1.3 (05/10).


Boiler 7 (EU 043)



Rate

Fuel Usage

Limits2

Maximum

Sulfur

Content3




4

(lb/MMscf)

Emission Rate

(lbs/hr)

Limited Potential

Emissions

(tons/yr)

Emission

Factor5

(lb/kgal)

Emission Rate

(lbs/hr)

Limited

Potential

Emissions

(tons/yr)

Emission Rate

(lbs/hr)

Limited

Potential

Emissions

(tons/yr)

PM 7.60 1.63 7.15 3.3 5.24 16.50 5.24 16.50

PM10 7.60 1.63 7.15 2.3 3.65 11.50 3.65 11.50

PM2.5 7.60 1.63 7.15 1.6 2.46 7.75 2.46 7.75

NOx6

190 40.79 39.00 24 38.09 39.00 40.79 39.00

SO2 0.6 0.13 0.56 7.1 11.27 35.50 11.27 35.50

CO 84 18.04 78.99 5 7.93 25.00 18.04 78.99

VOC 5.50 1.18 5.17 0.2 0.32 1.00 1.18 5.17

Lead 0.0005 0.00011 0.0005 NA ‐‐ ‐‐ 0.00011 0.0005

CO27

119,067 25,564 111,972 22,454 35,634 112,271 35,634 112,271

CH47

2.2 0.48 2.11 0.91 1.45 4.55 1.45 4.55

N2O7

0.22 0.05 0.21 0.18 0.29 0.91 0.29 0.91

CO2e8

119,190 25,591 112,087 ‐‐ 35,756 112,657 35,756 112,657

1 Heat values for 40 CFR Part 98, Table C‐1.2 No. 2 fuel oil limited to 10,000,000 gal/year3 Maximum permitted sulfur content of No. 2 Fuel Oil. 4 Emission factors from AP‐42, Section 1.4 (07/98)5 Emission factors from AP‐42, Section 1.3 (05/10). PM, PM10 and PM2.5 emission factors are are the sum of condensibles from

Table 1.3‐2 and filterable from Table 1.3‐6. The VOC emission factor is obtained from table 1.3‐3.6 NOx is limited in the permit to less than or equal to 39.0 tpy. Annual PM10, SO2 emissions are also limited, however, PTE is less than the limits.7 CO2, CH4 and N2O emission factors converted from Tables C‐1 and C‐2 to Subpart C of Part 988 CO2e is the sum of CO2, CH4 and N2O emissions times their respective global warming potential as listed in Table A‐1 to Subpart A of Part 98


Boiler 6 (EU 006)



Rate

Fuel Usage

Limits2

Maximum

Sulfur

Content3




4

(lb/MMscf)

Emission Rate

(lbs/hr)

Limited Potential

Emissions

(tons/yr)

Emission

Factor5

(lb/kgal)

Emission Rate

(lbs/hr)

Limited

Potential

Emissions

(tons/yr)

Emission Rate

(lbs/hr)

Limited

Potential

Emissions

(tons/yr)






Cobalt 8.40E‐05 1.80E‐05 7.90E‐05 ‐‐‐ ‐‐ ‐‐ 1.80E‐05 7.90E‐05

Dichlorobenzene 1.20E‐03 2.58E‐04 1.13E‐03 ‐‐‐ ‐‐ ‐‐ 2.58E‐04 1.13E‐03



Hexane 1.80 0.39 1.69 ‐‐‐ ‐‐ ‐‐ 0.39 1.69




Nickel 2.10E‐03 4.51E‐04 1.97E‐03 4.14E‐04 6.57E‐04 2.07E‐03 6.57E‐04 2.07E‐03

POM2 6.97E‐04 1.50E‐04 6.55E‐04 1.43E‐03 2.26E‐03 7.13E‐03 2.26E‐03 7.13E‐03



Xylene ‐‐ ‐‐ ‐‐ 1.09E‐04 1.73E‐04 5.45E‐04 1.73E‐04 5.45E‐04


1 Heat values for 40 CFR Part 98, Table C‐1.2 No. 2 fuel oil limited to 10,000,000 gal/year3 Maximum permitted sulfur content of No. 2 Fuel Oil. 4 Emission factors from AP‐42, Section 1.4 (07/98)5 Emission factors from AP‐42, Section 1.3 (05/10).


Natural Gas Generators

Fuel Operating HoursNatural Gas 500

EU No. Name kW BHP MMBtu/hr

EU 008 NG Generator 201‐731417 115 154 1.08

EU 009 NG Generator 205‐821913 80 107 0.75

EU 010 NG Generator 209‐734566 40 54 0.38

EU 016 NG Generator 230‐427957 175 235 1.64

EU 018 NG Generator 235‐EG0001 163 218 1.53


EU 052 NG Generator 216‐168605 125 168 1.17

EU 053 NG Generator 218‐321528 125 168 1.17

Total 1,003 1,345 9.41

* Emissions based on vendor or NSPS data included on a separate tab

Total Emissions:

Emission Factor1 Emission Rate

Potential

Emissions

Pollutant (lb/MMBtu) (lb/hr) (tpy)

PM 0.05 0.45 0.11

PM10 0.05 0.45 0.11

PM2.5 0.05 0.45 0.11

NOx 3.17 29.83 7.46

SO2 5.88E‐04 0.01 1.38E‐03

CO 0.386 3.63 0.91

VOC 0.12 1.13 0.28

CO22

116.732 1,099 275

CH42

2.20E‐03 0.02 5.2E‐03

N2O2

2.20E‐04 2.07E‐03 5.2E‐04

CO2e3

‐‐ 1,100 275

1 Emission factors from AP‐42, Section 3.2, table 3.2‐1. Worst‐case PM, PM10, and PM2.5 emissions are calculated

assuming the emission factor is equal to the PM condensable + PM10/PM2.5 filterable emission factors. NOx

and CO emission factors for 90 ‐ 105% load are used.2 CO2, CH4 and N2O emission factors converted from Tables C‐1 and C‐2 to Subpart C of Part 98.3 CO2e is the sum of CO2, CH4 and N2O emissions times their respective global warming potential as listed in Table A‐1 to Subpart A of Part 98

Generator Rating

Hourly Emissions for Individual Units:

Hourly Emissions per Pollutant (lb/hr)

EU No. PM/PM10/PM2.5 NOx SO2 CO VOC CO2 CH4 N2O CO2e

EU 008 0.05 3.42 6.3E‐04 0.42 0.13 125.96 2.37E‐03 2.37E‐04 126.09

EU 009 0.04 2.38 4.4E‐04 0.29 0.09 87.63 1.65E‐03 1.65E‐04 87.72

EU 010 0.02 1.19 2.2E‐04 0.14 0.05 43.81 8.26E‐04 8.26E‐05 43.86

EU 016 0.08 5.21 9.7E‐04 0.63 0.20 191.68 3.61E‐03 3.61E‐04 191.88

EU 018 0.07 4.85 9.0E‐04 0.59 0.18 178.54 3.36E‐03 3.36E‐04 178.72

EU 021 0.08 5.35 9.9E‐04 0.65 0.20 197.16 3.72E‐03 3.72E‐04 197.36

EU 052 0.06 3.72 6.9E‐04 0.45 0.14 136.92 2.58E‐03 2.58E‐04 137.06

EU 053 0.06 3.72 6.9E‐04 0.45 0.14 136.92 2.58E‐03 2.58E‐04 137.06

Annual Emissions for Individual Units:

Annual Emissions per Pollutant (tpy)


EU 008 0.01 0.86 0.00 0.10 0.03 31.49 0.00 0.00 31.52

EU 009 0.01 0.59 0.00 0.07 0.02 21.91 0.00 0.00 21.93

EU 010 0.00 0.30 0.00 0.04 0.01 10.95 0.00 0.00 10.96

EU 016 0.02 1.30 0.00 0.16 0.05 47.92 0.00 0.00 47.97

EU 018 0.02 1.21 0.00 0.15 0.05 44.64 0.00 0.00 44.68

EU 021 0.02 1.34 0.00 0.16 0.05 49.29 0.00 0.00 49.34

EU 052 0.01 0.93 0.00 0.11 0.04 34.23 0.00 0.00 34.26

EU 053 0.01 0.93 0.00 0.11 0.04 34.23 0.00 0.00 34.26

Natural Gas Generators

Fuel Operating HoursNatural Gas 500


EU 008 NG Generator 201‐731417 115 154 1.1

EU 009 NG Generator 205‐821913 80 107 0.8

EU 010 NG Generator 209‐734566 40 54 0.4

EU 016 NG Generator 230‐427957 175 235 1.6



EU 052 NG Generator 216‐168605 125 168 1.2

EU 053 NG Generator 218‐321528 125 168 1.2

Total 1,003 1,345 9.4

Total Emissions:

Emission Factor Emission Rate

Potential

Emissions

Pollutant CAS (lb/MMBtu) (lb/hr) (tpy)

1,1,2,2‐Tetrachloroethane 6.63E‐05 6.24E‐04 1.56E‐04

1,1,2‐Trichloroethane 5.27E‐05 4.96E‐04 1.24E‐04

1,3‐Butadiene 8.20E‐04 7.72E‐03 1.93E‐03

1,3‐Dichloropropene 4.38E‐05 4.12E‐04 1.03E‐04

2,2,4‐Trimethylpentane 8.46E‐04 7.96E‐03 1.99E‐03

2‐Methylnaphthalene 2.14E‐05 2.01E‐04 5.04E‐05

Acenaphthene 1.33E‐06 1.25E‐05 3.13E‐06

Acenaphthylene 3.17E‐06 2.98E‐05 7.46E‐06

Acetaldehyde 7.76E‐03 7.30E‐02 1.83E‐02

Acrolein 7.78E‐03 7.32E‐02 1.83E‐02

Anthracene 7.18E‐07 6.76E‐06 1.69E‐06

Benz(a)anthracene 3.36E‐07 3.16E‐06 7.91E‐07

Benzene 1.94E‐03 1.83E‐02 4.56E‐03

Benzo(a)pyrene 5.68E‐09 5.35E‐08 1.34E‐08

Benzo(b)fluoranthene 8.51E‐09 8.01E‐08 2.00E‐08

Benzo(e)pyrene 2.34E‐08 2.20E‐07 5.51E‐08

Benzo(g,h,i)perylene 2.48E‐08 2.33E‐07 5.84E‐08

Benzo(k)fluoranthene 4.26E‐09 4.01E‐08 1.00E‐08

Biphenyl 3.95E‐06 3.72E‐05 9.29E‐06

Carbon Tetrachloride 6.07E‐05 5.71E‐04 1.43E‐04

Chlorobenzene 4.44E‐05 4.18E‐04 1.04E‐04

Chloroform 4.71E‐05 4.43E‐04 1.11E‐04

Chrysene 6.72E‐07 6.32E‐06 1.58E‐06

Ethylbenzene 1.08E‐04 1.02E‐03 2.54E‐04

Ethylene Dibromide 7.34E‐05 6.91E‐04 1.73E‐04

Fluoranthene 3.61E‐07 3.40E‐06 8.49E‐07

Fluorene 1.69E‐06 1.59E‐05 3.98E‐06

Formaldehyde 5.52E‐02 5.20E‐01 1.30E‐01

Indeno(1,2,3c‐d)pyrene 9.93E‐09 9.35E‐08 2.34E‐08

Methanol 2.48E‐03 2.33E‐02 5.84E‐03

Methylene Chloride 1.47E‐04 1.38E‐03 3.46E‐04

n‐Hexane 4.45E‐04 4.19E‐03 1.05E‐03

Naphthalene 9.63E‐05 9.06E‐04 2.27E‐04

PAH 1.34E‐04 1.26E‐03 3.15E‐04

Perylene 4.97E‐09 4.68E‐08 1.17E‐08

Phenanthrene 3.53E‐06 3.32E‐05 8.31E‐06

Phenol 4.21E‐05 3.96E‐04 9.91E‐05

Pyrene 5.84E‐07 5.50E‐06 1.37E‐06

Styrene 5.48E‐05 5.16E‐04 1.29E‐04

Toluene 9.63E‐04 9.06E‐03 2.27E‐03

Vinyl Chloride 2.47E‐05 2.32E‐04 5.81E‐05

Xylene 2.68E‐04 2.52E‐03 6.31E‐04

Total Emissions: 7.47E‐01 1.87E‐01

1 Emission factors from AP‐42, Section 3.2.

Generator Rating



EU No. 1,3‐Butadiene

2,2,4‐

Trimethylpent

ane

Acetaldehyde Acrolein Benzene Ethylbenzene Formaldehyde MethanolMethylene

Chloriden‐Hexane Naphthalene Styrene Toluene Vinyl Chloride Xylene Total

EU 008 8.85E‐04 9.13E‐04 8.37E‐03 8.40E‐03 2.09E‐03 1.17E‐04 5.96E‐02 2.68E‐03 1.59E‐04 4.80E‐04 1.04E‐04 5.91E‐05 1.04E‐03 2.67E‐05 2.89E‐04 8.52E‐02










EU No. 1,3‐Butadiene

2,2,4‐

Trimethylpent

ane

Acetaldehyde Acrolein Benzene Ethylbenzene Formaldehyde MethanolMethylene

Chloriden‐Hexane Naphthalene Styrene Toluene Vinyl Chloride Xylene Total









Diesel Generators < 600 HP

Fuel Operating Hours

Maximum

Sulfur

Content1

Diesel 500 0.5%


EU 025 Diesel Generator 223‐427829 312 418 2.9




EU 047 Diesel Generator 278 27 37 0.256



EU 050 Fire Pump 217‐00001 119 160 1.1

Total 1,908 2,558 17.9


Total Emissions:


Potential

Emissions


PM 0.31 5.55 1.39

PM10 0.31 5.55 1.39

PM2.5 0.31 5.55 1.39

NOx 4.41 78.97 19.74

SO2 0.29 5.19 1.30

CO 0.95 17.01 4.25

VOC 0.36 6.45 1.61

CO23

163 2,913.54 728.39

CH43

6.60E‐03 0.12 0.03

N2O3

1.32E‐03 0.02 0.01

CO2e4

‐‐ 2,924 731

1 Maximum sulfur content of No. 2 Fuel Oil allowed under Minnesota Rules. Actual values are significantly lower.2 Emission factors from AP‐42, Section 3.33 CO2, CH4 and N2O emission factors converted from Tables C‐1 and C‐2 to Subpart C of Part 98.4 CO2e is the sum of CO2, CH4 and N2O emissions times their respective global warming potential

Generator Rating

as listed in Table A‐1 to Subpart A of Part 98




EU 025 0.91 12.91 0.85 2.78 1.05 476.36 1.93E‐02 3.86E‐03 477.99

EU 027 1.16 16.55 1.09 3.57 1.35 610.72 2.48E‐02 4.95E‐03 612.81

EU 031 0.44 6.21 0.41 1.34 0.51 229.02 9.29E‐03 1.86E‐03 229.80

EU 037 1.16 16.55 1.09 3.57 1.35 610.72 2.48E‐02 4.95E‐03 612.81

EU 047 0.08 1.13 0.07 0.24 0.09 41.65 1.69E‐03 3.38E‐04 41.80

EU 048 0.73 10.35 0.68 2.23 0.84 381.70 1.55E‐02 3.10E‐03 383.01

EU 049 0.73 10.35 0.68 2.23 0.84 381.70 1.55E‐02 3.10E‐03 383.01

EU 050 0.35 4.92 0.32 1.06 0.40 181.69 7.37E‐03 1.47E‐03 182.31




EU 025 0.23 3.23 0.21 0.70 0.26 119.09 0.00 0.00 119.50

EU 027 0.29 4.14 0.27 0.89 0.34 152.68 0.01 0.00 153.20

EU 031 0.11 1.55 0.10 0.33 0.13 57.25 0.00 0.00 57.45

EU 037 0.29 4.14 0.27 0.89 0.34 152.68 0.01 0.00 153.20

EU 047 0.02 0.28 0.02 0.06 0.02 10.41 0.00 0.00 10.45

EU 048 0.18 2.59 0.17 0.56 0.21 95.42 0.00 0.00 95.75

EU 049 0.18 2.59 0.17 0.56 0.21 95.42 0.00 0.00 95.75

EU 050 0.09 1.23 0.08 0.27 0.10 45.42 0.00 0.00 45.58

Diesel Generators < 600 HP


Maximum

Sulfur

Content1

Diesel 500 0.5%









EU 050 Fire Pump 217‐00001 119 160 1.1

Total 1,908 2,558 17.9

Total Emissions:


Potential

Emissions


Benzene 9.33E‐04 1.67E‐02 4.18E‐03

Toluene 4.09E‐04 7.32E‐03 1.83E‐03

Xylene 2.85E‐04 5.10E‐03 1.28E‐03

1,3‐Butadiene 3.91E‐05 7.00E‐04 1.75E‐04

Formaldehyde 1.18E‐03 2.11E‐02 5.28E‐03

Acetaldehyde 7.67E‐04 1.37E‐02 3.43E‐03

Acrolein 9.25E‐05 1.66E‐03 4.14E‐04

Naphthalene 8.48E‐05 1.52E‐03 3.80E‐04

PAH 1.68E‐04 3.01E‐03 7.52E‐04

Total Emissions: 7.09E‐02 1.77E‐021 Maximum sulfur content of No. 2 Fuel Oil allowed under Minnesota Rules. Actual values are significantly lower.2 Emission factors from AP‐42, Section 3.3



EU No. Benzene Toluene Xylene 1,3‐Butadiene Formaldehyde Acetaldehyde Acrolein Naphthalene PAH

EU 025 2.73E‐03 1.20E‐03 8.34E‐04 1.14E‐04 3.45E‐03 2.25E‐03 2.71E‐04 2.48E‐04 4.92E‐04

EU 027 3.50E‐03 1.54E‐03 1.07E‐03 1.47E‐04 4.43E‐03 2.88E‐03 3.47E‐04 3.18E‐04 6.31E‐04

Generator Rating

EU 031 1.31E‐03 5.76E‐04 4.01E‐04 5.50E‐05 1.66E‐03 1.08E‐03 1.30E‐04 1.19E‐04 2.36E‐04

EU 037 3.50E‐03 1.54E‐03 1.07E‐03 1.47E‐04 4.43E‐03 2.88E‐03 3.47E‐04 3.18E‐04 6.31E‐04

EU 047 2.39E‐04 1.05E‐04 7.30E‐05 1.00E‐05 3.02E‐04 1.96E‐04 2.37E‐05 2.17E‐05 4.30E‐05

EU 048 2.19E‐03 9.59E‐04 6.69E‐04 9.17E‐05 2.77E‐03 1.80E‐03 2.17E‐04 1.99E‐04 3.94E‐04

EU 049 2.19E‐03 9.59E‐04 6.69E‐04 9.17E‐05 2.77E‐03 1.80E‐03 2.17E‐04 1.99E‐04 3.94E‐04

EU 050 1.04E‐03 4.57E‐04 3.18E‐04 4.37E‐05 1.32E‐03 8.56E‐04 1.03E‐04 9.47E‐05 1.88E‐04



EU No. Benzene Toluene Xylene 1,3‐Butadiene Formaldehyde Acetaldehyde Acrolein Naphthalene PAH

EU 025 6.83E‐04 2.99E‐04 2.09E‐04 2.86E‐05 8.64E‐04 5.61E‐04 6.77E‐05 6.21E‐05 1.23E‐04

EU 027 8.75E‐04 3.84E‐04 2.67E‐04 3.67E‐05 1.11E‐03 7.20E‐04 8.68E‐05 7.96E‐05 1.58E‐04

EU 031 3.28E‐04 1.44E‐04 1.00E‐04 1.38E‐05 4.15E‐04 2.70E‐04 3.25E‐05 2.98E‐05 5.91E‐05

EU 037 8.75E‐04 3.84E‐04 2.67E‐04 3.67E‐05 1.11E‐03 7.20E‐04 8.68E‐05 7.96E‐05 1.58E‐04

EU 047 5.97E‐05 2.62E‐05 1.82E‐05 2.50E‐06 7.55E‐05 4.91E‐05 5.92E‐06 5.43E‐06 1.08E‐05

EU 048 5.47E‐04 2.40E‐04 1.67E‐04 2.29E‐05 6.92E‐04 4.50E‐04 5.42E‐05 4.97E‐05 9.85E‐05

EU 049 5.47E‐04 2.40E‐04 1.67E‐04 2.29E‐05 6.92E‐04 4.50E‐04 5.42E‐05 4.97E‐05 9.85E‐05

EU 050 2.60E‐04 1.14E‐04 7.96E‐05 1.09E‐05 3.29E‐04 2.14E‐04 2.58E‐05 2.37E‐05 4.69E‐05

Diesel Generators > 600 HP


Maximum

Sulfur

Content1

Diesel 500 0.5%


EU 028 Diesel Generator 277‐EG0001 800 1072 7.5



EU 032 Diesel Generator 5 243‐512084 600 804 5.6








EU 051* Diesel Generator 217‐494480 450 603 4.2

EU 054* Diesel Generator 210‐296269 450 603 4.2

EU 055* Diesel Generator 280 750 1005 7.0

Total 7,700 10,322 72.3


Total Emissions:


Potential

Emissions


PM 0.0697 5.04 1.26

PM10 0.0573 4.14 1.04

PM2.5 0.0556 4.02 1.00

NOx 3.20 231.21 57.80

SO2 0.51 36.49 9.12

CO 0.85 61.41 15.35

VOC 0.08 5.92 1.48

CO23

163 11,756.27 2,939.07

CH43

6.60E‐03 0.48 0.12

N2O3

1.32E‐03 0.10 0.02

CO2e4

‐‐ 11,797 2,949

1 Maximum sulfur content of No. 2 Fuel Oil allowed under Minnesota Rules. Actual values are significantly lower.

Generator Rating

Only Three

Engines Can

Operate at

Any Time

2 Emission factors from AP‐42, Section 3.4, tables 3.4‐1 and 3.4‐2. PM10 emissions are based on the sum of table 3.4‐2

filterable particulate <10 um emission factor and the condensable particulate emission factor. PM2.5 emissions are

3 CO2, CH4 and N2O emission factors converted from Tables C‐1 and C‐2 to Subpart C of Part 98.4 CO2e is the sum of CO2, CH4 and N2O emissions times their respective global warming potential

as listed in Table A‐1 to Subpart A of Part 98



EU No. PM PM10 PM2.5 NOx SO2 CO VOC CO2 CH4 N2O CO2e

EU 028 0.52 0.43 0.42 24.02 3.79 6.38 0.61 1221.43 0.05 0.01 1225.62

EU 029 0.52 0.43 0.42 24.02 3.79 6.38 0.61 1221.43 0.05 0.01 1225.62

EU 030 0.52 0.43 0.42 24.02 3.79 6.38 0.61 1221.43 0.05 0.01 1225.62

EU 032 0.39 0.32 0.31 18.02 2.84 4.79 0.46 916.07 0.04 0.01 919.22

EU 033 0.39 0.32 0.31 18.02 2.84 4.79 0.46 916.07 0.04 0.01 919.22

EU 034 0.39 0.32 0.31 18.02 2.84 4.79 0.46 916.07 0.04 0.01 919.22

EU 035 0.39 0.32 0.31 18.02 2.84 4.79 0.46 916.07 0.04 0.01 919.22

EU 036 0.39 0.32 0.31 18.02 2.84 4.79 0.46 916.07 0.04 0.01 919.22

EU 038 0.33 0.27 0.26 15.01 2.37 3.99 0.38 763.39 0.03 0.01 766.01

EU 039 0.39 0.32 0.31 18.02 2.84 4.79 0.46 916.07 0.04 0.01 919.22

EU 040 0.49 0.40 0.39 22.52 3.55 5.98 0.58 1145.09 0.05 0.01 1149.02

EU 051* See additional tab for emission calculations





EU No. PM PM10 PM2.5 NOx SO2 CO VOC CO2 CH4 N2O CO2e

EU 028 0.13 0.11 0.10 6.01 0.95 1.60 0.15 305.36 0.01 0.00 306.41

EU 029 0.13 0.11 0.10 6.01 0.95 1.60 0.15 305.36 0.01 0.00 306.41

EU 030 0.13 0.11 0.10 6.01 0.95 1.60 0.15 305.36 0.01 0.00 306.41

EU 032 0.10 0.08 0.08 4.50 0.71 1.20 0.12 229.02 0.01 0.00 229.80

EU 033 0.10 0.08 0.08 4.50 0.71 1.20 0.12 229.02 0.01 0.00 229.80

EU 034 0.10 0.08 0.08 4.50 0.71 1.20 0.12 229.02 0.01 0.00 229.80

EU 035 0.10 0.08 0.08 4.50 0.71 1.20 0.12 229.02 0.01 0.00 229.80

EU 036 0.10 0.08 0.08 4.50 0.71 1.20 0.12 229.02 0.01 0.00 229.80

EU 038 0.08 0.07 0.07 3.75 0.59 1.00 0.10 190.85 0.01 0.00 191.50

EU 039 0.10 0.08 0.08 4.50 0.71 1.20 0.12 229.02 0.01 0.00 229.80

EU 040 0.12 0.10 0.10 5.63 0.89 1.50 0.14 286.27 0.01 0.00 287.26




based on the sum of table 3.4‐1 filterable particulate <3 um emission factor and the condensible particulate emisison

factor.

Diesel Generators > 600 HP


Maximum

Sulfur

Content1

Diesel 500 0.5%

Size (138 MMBtu/1000 gal)

EU No. Name kW BHP MMBtu/hr 103 gal/hr

EU 028 Diesel Generator 277‐EG0001 800 1072 7.5 0.054



EU 032 Diesel Generator 5 243‐512084 600 804 5.6 0.041





EU 038 Diesel Generator 260‐469589 500 670 4.7 0.034





EU 055 Diesel Generator 280 750 1005 7.0 0.051

Total 7,700 10,322 72.3 0.5

Total Emissions:

Emission Emission Rate

Potential

Emissions

Factor3

(lb/hr) (tpy)

(lb/103 Gal)

Acetaldehyde5 [75‐07‐0] 2.52E‐05 1.32E‐05 3.30E‐06

Acrolein5 [107‐02‐8] 7.88E‐06 4.13E‐06 1.03E‐06

Benzene5 [71‐43‐2] 7.76E‐04 4.06E‐04 1.02E‐04

Formaldehyde5 [50‐00‐0] 7.89E‐05 4.13E‐05 1.03E‐05

Naphthalene5 [91‐20‐3] 1.30E‐04 6.81E‐05 1.70E‐05

Toluene5 [108‐88‐3] 2.81E‐04 1.47E‐04 3.68E‐05

Xylene5 [95‐47‐6] 1.93E‐04 1.01E‐04 2.53E‐05

PAH NA 2.12E‐04 1.11E‐04 2.77E‐05

Total 8.92E‐04 2.23E‐04

3Emission Factors from AP‐42 "Fuel Oil Combustion", Tables 1.3‐9 and 1.3‐10 dated 05/10.4POM emission factor from AP‐42 "Fuel Oil Combustion" Table 1.3‐8 dated 5/105Emission Factor from AP‐42 Table 3.4‐3.


EU No. Acetaldehyde Acrolein Benzene Formaldehyde Naphthalene Toluene Xylene PAH Total

EU 028 1.37E‐06 4.29E‐07 4.22E‐05 4.29E‐06 7.07E‐06 1.53E‐05 1.05E‐05 1.15E‐05 9.27E‐05

EU 029 1.37E‐06 4.29E‐07 4.22E‐05 4.29E‐06 7.07E‐06 1.53E‐05 1.05E‐05 1.15E‐05 9.27E‐05

EU 030 1.37E‐06 4.29E‐07 4.22E‐05 4.29E‐06 7.07E‐06 1.53E‐05 1.05E‐05 1.15E‐05 9.27E‐05

EU 032 1.03E‐06 3.21E‐07 3.17E‐05 3.22E‐06 5.30E‐06 1.15E‐05 7.87E‐06 8.65E‐06 6.95E‐05

EU 033 1.03E‐06 3.21E‐07 3.17E‐05 3.22E‐06 5.30E‐06 1.15E‐05 7.87E‐06 8.65E‐06 6.95E‐05

EU 034 1.03E‐06 3.21E‐07 3.17E‐05 3.22E‐06 5.30E‐06 1.15E‐05 7.87E‐06 8.65E‐06 6.95E‐05

EU 035 1.03E‐06 3.21E‐07 3.17E‐05 3.22E‐06 5.30E‐06 1.15E‐05 7.87E‐06 8.65E‐06 6.95E‐05

EU 036 1.03E‐06 3.21E‐07 3.17E‐05 3.22E‐06 5.30E‐06 1.15E‐05 7.87E‐06 8.65E‐06 6.95E‐05

EU 038 8.57E‐07 2.68E‐07 2.64E‐05 2.68E‐06 4.42E‐06 9.55E‐06 6.56E‐06 7.21E‐06 5.79E‐05

EU 039 1.03E‐06 3.21E‐07 3.17E‐05 3.22E‐06 5.30E‐06 1.15E‐05 7.87E‐06 8.65E‐06 6.95E‐05

EU 040 1.29E‐06 4.02E‐07 3.96E‐05 4.02E‐06 6.63E‐06 1.43E‐05 9.84E‐06 1.08E‐05 8.69E‐05

EU 051 7.71E‐07 2.41E‐07 2.37E‐05 2.41E‐06 3.98E‐06 8.60E‐06 5.91E‐06 6.49E‐06 5.21E‐05

EU 054 7.71E‐07 2.41E‐07 2.37E‐05 2.41E‐06 3.98E‐06 8.60E‐06 5.91E‐06 6.49E‐06 5.21E‐05

EU 055 1.29E‐06 4.02E‐07 3.96E‐05 4.02E‐06 6.63E‐06 1.43E‐05 9.84E‐06 1.08E‐05 8.69E‐05


EU No. Acetaldehyde Acrolein Benzene Formaldehyde Naphthalene Toluene Xylene PAH Total

EU 028 3.43E‐07 1.07E‐07 1.06E‐05 1.07E‐06 1.77E‐06 3.82E‐06 2.62E‐06 2.88E‐06 2.32E‐05

EU 029 3.43E‐07 1.07E‐07 1.06E‐05 1.07E‐06 1.77E‐06 3.82E‐06 2.62E‐06 2.88E‐06 2.32E‐05

EU 030 3.43E‐07 1.07E‐07 1.06E‐05 1.07E‐06 1.77E‐06 3.82E‐06 2.62E‐06 2.88E‐06 2.32E‐05

EU 032 2.57E‐07 8.04E‐08 7.91E‐06 8.05E‐07 1.33E‐06 2.87E‐06 1.97E‐06 2.16E‐06 1.74E‐05

EU 033 2.57E‐07 8.04E‐08 7.91E‐06 8.05E‐07 1.33E‐06 2.87E‐06 1.97E‐06 2.16E‐06 1.74E‐05

EU 034 2.57E‐07 8.04E‐08 7.91E‐06 8.05E‐07 1.33E‐06 2.87E‐06 1.97E‐06 2.16E‐06 1.74E‐05

EU 035 2.57E‐07 8.04E‐08 7.91E‐06 8.05E‐07 1.33E‐06 2.87E‐06 1.97E‐06 2.16E‐06 1.74E‐05

EU 036 2.57E‐07 8.04E‐08 7.91E‐06 8.05E‐07 1.33E‐06 2.87E‐06 1.97E‐06 2.16E‐06 1.74E‐05

EU 038 2.14E‐07 6.70E‐08 6.60E‐06 6.71E‐07 1.10E‐06 2.39E‐06 1.64E‐06 1.80E‐06 1.45E‐05

EU 039 2.57E‐07 8.04E‐08 7.91E‐06 8.05E‐07 1.33E‐06 2.87E‐06 1.97E‐06 2.16E‐06 1.74E‐05

EU 040 3.21E‐07 1.00E‐07 9.89E‐06 1.01E‐06 1.66E‐06 3.58E‐06 2.46E‐06 2.70E‐06 2.17E‐05

EU 051 1.93E‐07 6.03E‐08 5.94E‐06 6.04E‐07 9.94E‐07 2.15E‐06 1.48E‐06 1.62E‐06 1.30E‐05

EU 054 1.93E‐07 6.03E‐08 5.94E‐06 6.04E‐07 9.94E‐07 2.15E‐06 1.48E‐06 1.62E‐06 1.30E‐05

EU 055 3.21E‐07 1.00E‐07 9.89E‐06 1.01E‐06 1.66E‐06 3.58E‐06 2.46E‐06 2.70E‐06 2.17E‐05


Annual Emissions per Pollutant (ton/year)

Generator Rating

Only Three

Engines Can

Operate at

Any Time

HAP Name

(CAS)

Building 278 Natural Gas Boilers (EU 043, 044 & 045))

2 MMBtu/hr each

6 MMBtu/hr total


Consumption

Rate

Natural Gas 1,020 Btu/scf 0.006 MMscf/hr


(lb/MMscf)

Emission Rate ‐

Total

(lbs/hr)

Emission Rate ‐

Each

(lbs/hr)

Potential

Emissions ‐ Total

(tons/yr)

Potential

Emissions ‐ Each

(tons/yr)

PM 7.60 0.04 0.01 0.20 0.07

PM10 7.60 0.04 0.01 0.20 0.07

PM2.5 7.60 0.04 0.01 0.20 0.07

NOx 100 0.59 0.20 2.58 0.86

SO2 0.6 3.53E‐03 0.001 0.02 0.01

CO 84 0.49 0.16 2.16 0.72

VOC 5.5 0.03 0.01 0.14 0.05

Lead 0.0005 2.94E‐06 0.00 0.00001 0.00

CO23

119,067 700 233.46 3,068 1,022.57

CH43

2.2 0.01 0.00 0.06 0.02

N2O3

0.22 1.32E‐03 0.00 0.01 0.00

CO2e4

119,190 701 233.71 3,071 1,023.63

1 Heat values for 40 CFR Part 98, Table C‐1.2 Emission factors from AP‐42, Section 1.4 (07/98)3 CO2, CH4 and N2O emission factors converted from Tables C‐1 and C‐2 to Subpart C of Part 984 CO2e is the sum of CO2, CH4 and N2O emissions times their respective

global warming potential as listed in Table A‐1 to Subpart A of Part 98

Design Heat Input

Building 278 Natural Gas Boilers (EU 043, 044 & 045))

2 MMBtu/hr each

6 MMBtu/hr total


Consumption

Rate

Natural Gas 1,020 Btu/scf 0.006 MMscf/hr

Pollutant CASEmission Factor2

(lb/MMscf)

Emission Rate ‐

Total

(lbs/hr)

Emission Rate ‐

Each

(lbs/hr)

Potential

Emissions ‐ Total

(tons/yr)

Potential

Emissions ‐

Each

(tons/yr)

Arsenic [7440‐38‐2] 2.0E‐04 1.18E‐06 3.92E‐07 5.15E‐06 1.72E‐06

Benzene [71‐43‐2] 2.1E‐03 1.24E‐05 4.12E‐06 5.41E‐05 1.80E‐05

Beryllium [7440‐41‐7] 1.2E‐05 7.06E‐08 2.35E‐08 3.09E‐07 1.03E‐07

Cadmium [7440‐43‐9] 1.1E‐03 6.47E‐06 2.16E‐06 2.83E‐05 9.45E‐06

Chromium [7440‐47‐3] 1.4E‐03 8.24E‐06 2.75E‐06 3.61E‐05 1.20E‐05

Cobalt [7440‐48‐4] 8.4E‐05 4.94E‐07 1.65E‐07 2.16E‐06 7.21E‐07

Dichlorobenzene [25321‐22‐6] 1.2E‐03 7.06E‐06 2.35E‐06 3.09E‐05 1.03E‐05

Formaldehyde [50‐00‐0] 7.5E‐02 4.41E‐04 1.47E‐04 1.93E‐03 6.44E‐04

Hexane [110‐54‐3] 1.8E+00 1.06E‐02 3.53E‐03 4.64E‐02 1.55E‐02

Manganese [7439‐96‐5] 3.8E‐04 2.24E‐06 7.45E‐07 9.79E‐06 3.26E‐06

Mercury [7439‐97‐6] 2.6E‐04 1.53E‐06 5.10E‐07 6.70E‐06 2.23E‐06

Naphthalene [91‐20‐3] 6.1E‐04 3.59E‐06 1.20E‐06 1.57E‐05 5.24E‐06

Nickel [7440‐02‐0] 2.1E‐03 1.24E‐05 4.12E‐06 5.41E‐05 1.80E‐05

POM2 NA 6.97E‐04 4.10E‐06 1.37E‐06 1.80E‐05 5.99E‐06

Selenium [7782‐49‐2] 2.4E‐05 1.41E‐07 4.71E‐08 6.18E‐07 2.06E‐07

Toluene [108‐88‐3] 3.4E‐03 2.00E‐05 6.67E‐06 8.76E‐05 2.92E‐05

Total Emissions 1.11E‐02 3.70E‐03 4.87E‐02 1.62E‐02

1 Heat values for 40 CFR Part 98, Table C‐1.2 Emission factors from AP‐42, Section 1.4 (07/98)

Design Heat Input

Diesel Generator ‐ Data Summary

Emission Size Size Size Size

Unit No. SV No. kW hp million BTU/hr (<600 HP or >600 HP)

EU 051 SV 051 450 603 4.22 Large

Emission Factors ‐ Fuel Oil

Emission Emission Emission

Pollutant Factor Factor Factor

Units Source

PM 0.20 g/KW‐hr NSPS Subpart IIII2

PM10 0.20 g/KW‐hr NSPS Subpart IIII2

PM2.5 0.20 g/KW‐hr NSPS Subpart IIII2

SO2 1.52E‐05 lb/MMBtu AP‐42 Table 3.4‐11

NOx 4.00 g/KW‐hr NSPS Subpart IIII2

VOC 0.09 lb/MMBtu AP‐42 Table 3.4‐1

CO 3.50 g/KW‐hr NSPS Subpart IIII2

1 Based on 15 ppm sulfur.2 NSPS Subpart IIII limits are for Tier 3 certified units of 450 kW size (40 CFR Part 89.112 Table 1)

Emission Calculations ‐ Large Diesel Based on NSPS LimitsMaximum Controlled Maximum Limited (500 hrs)

Emission Pollutant Emission Uncontrolled Control Emission Controlled ControlledUnit No. Rate Emissions Efficiency Rate Emissions Emissions

lbs/hr tpy % lbs/hr tpy tpy

PM 0.20 0.87 0.00% 0.20 0.87 0.05

PM10 0.20 0.87 0.00% 0.20 0.87 0.05

PM2.5 0.20 0.87 0.00% 0.20 0.87 0.05

SO2 6.39E‐05 2.80E‐04 0.00% 6.39E‐05 2.80E‐04 1.60E‐05

NOx 3.97 17.38 0.00% 3.97 17.38 0.99

VOC 0.38 1.66 0.00% 0.38 1.66 0.09

CO 3.47 15.21 0.00% 3.47 15.21 0.87

Fuel Oil:

PollutantGlobal Warming

Potential FactorEmission factor 1 Emission factor Emission Rate Emission Rate

Limited (500 hrs)

Emission Rate

kg/MMBtu lb/MMBtu lb/hr ton/yr ton/yr

CO2 1 73.96 163 688 3,015 172

CH4 25 3.0E‐03 6.61E‐03 2.79E‐02 0.12 0.01

N2O 298 6.0E‐04 1.32E‐03 5.58E‐03 0.02 1.40E‐03

Total CO2e 691 3,025 173

Emission

Unit Desc.

Diesel Generator Bldg. 217

> 600 HP

EU 051



Unit No. SV No. kW hp million BTU/hr (<600 HPor >600 HP)

EU 054 SV 054 Diesel Generator ‐‐‐ 450 603.2 4.22 Large




Units Source

PM 2.00E‐01 g/KW‐hr NSPS Subpart IIII

PM10 2.00E‐01 g/KW‐hr NSPS Subpart IIII

PM2.5 2.00E‐01 g/KW‐hr NSPS Subpart IIII

SO2 1.52E‐01 lb/MMBtu AP‐42 Table 3.3‐11

NOx 6.40E+00 g/KW‐hr NSPS Subpart IIII

VOC 9.00E‐02 lb/MMBtu AP‐42 Table 3.3‐1

CO 3.50E+00 g/KW‐hr NSPS Subpart IIII

Emission Calculations ‐ Large Diesel

Maximum Limited

Emission Pollutant Emission Controlled Controlled

Unit No. Rate Emissions Emissions

lbs/hr tpy tpy

PM 0.20 0.87 0.05

PM10 0.20 0.87 0.05

PM2.5 0.20 0.87 0.05

SO2 0.64 2.80 0.16

NOx 6.35 27.81 1.59

VOC 0.38 1.66 0.10

CO 3.47 15.21 0.871 Based on 0.15% sulfur. This is a conservative assumption.

Fuel Oil:



Limited (500 hrs)

Emission Rate


CO2 1 73.96 163 688 3,016 172

CH4 25 3.0E‐03 6.61E‐03 2.79E‐02 0.12 0.01

N2O 298 6.0E‐04 1.32E‐03 5.59E‐03 0.02 1.40E‐03

Total CO2e 691 3,026 173

Emission

Unit Desc.

> 600 HP

Unit to Be

Installed

P:\23\68\004\PSD Application\3M Center Admin PTE Calcs - 07 14 14.xlsx EU 054 - Criteria 26 of 29 9/19/2014



Unit No. SV No. kW hp million BTU/hr (<600 HPor >600 HP)

EU 055 SV 055 750 1005 7.04 Large




Units Source

PM 0.20 g/KW‐hr NSPS Subpart IIII2

PM10 0.20 g/KW‐hr NSPS Subpart IIII2

PM2.5 0.20 g/KW‐hr NSPS Subpart IIII2

SO2 0.15 lb/MMBtu AP‐42 Table 3.4‐11

NOx 6.40 g/KW‐hr NSPS Subpart IIII2

VOC 9.00E‐02 lb/MMBtu AP‐42 Table 3.4‐11

CO 3.50 g/KW‐hr NSPS Subpart IIII2

1 Based on 0.15% sulfur. This is a conservative assumption.2 NSPS Subpart IIII limits are for Tier 2 certified units (40 CFR Part 89.112 Table 1)

Emission Calculations ‐ Large Diesel Based on NSPS LimitsMaximum Controlled Maximum Limited (500 hrs)

Emission Pollutant Emission Uncontrolled Control Emission Controlled ControlledUnit No. Rate Emissions Efficiency3 Rate Emissions Emissions

lbs/hr tpy % lbs/hr tpy tpy

PM 0.33 0.08 85.00% 0.05 0.22 0.01

PM10 0.33 0.08 85.00% 0.05 0.22 0.01

PM2.5 0.33 0.08 85.00% 0.05 0.22 0.01

SO2 1.07 0.27 0.00% 1.07 4.67 0.27

NOx 10.58 2.65 0.00% 10.58 46.35 2.65

VOC 0.63 0.16 0.00% 0.63 2.77 0.16

CO 5.79 1.45 90.00% 0.58 2.53 0.143 Based on ELM Energy LLC diesel particulate filter PM Clarity 750 System Specifications.

Fuel Oil:



Limited (500 hrs)

Emission Rate


CO2 1 74.0 163 1147 5,026 287

CH4 25 3.00E‐03 6.61E‐03 4.65E‐02 0.20 0.01

N2O 298 6.00E‐04 1.32E‐03 9.31E‐03 0.04 2.33E‐03

Total CO2e 1,151 5,043 288

1 Subpart C of 40 CFR Part 98. CO2 factors from Table C‐1 for "Natural Gasoline" and "Fuel Oil No.2"; CH4 and N2O factors from Table C‐2 for "Natural Gasoline" and "Petroleum".

Values converted to lb.

Emission

Unit Desc.

Detroit Diesel Generator 750‐XC6DT2

> 600 HP

055

AQ Facility ID No.: 12300694

Facility Name: 3M Company

Cooling Tower Emissions

Total Max PM PM PM10 PM10 PM2.5 PM2.5

Liquid Measured Emission Potential to Emission Potential to Emission Potential to

OLD Stack Date MPCA Drift TDS Rate Emit (PTE) Rate Emit (PTE) Rate Emit (PTE)

Unit # Unit ID ID Unit Name Installed Units Pollutant (lb/hr) (ppm) (lb/hr) (ton/yr) (lb/hr) (ton/yr) (lb/hr) (ton/yr)

CT7W EU041 SV041_A_Admin Cooling Tower 7W 1982 PM/PM10 450,000 gal/hr 4.17E‐04 1 187.65 980 0.184 0.805 0.151 0.663 0.001 0.002

CT7E EU041 SV041_B_Admin Cooling Tower 7E 1982 PM/PM10 450,000 gal/hr 4.17E‐04 1 187.65 980 0.184 0.805 0.151 0.663 0.001 0.002

CT6EN EU041 SV041_C_Admin Cooling Tower 6EN 1976 PM/PM10 210,000 gal/hr 4.17E‐04 1 87.57 980 0.086 0.376 0.071 0.309 0.000 0.001

CT6N EU041 SV041_D_Admin Cooling Tower 6N 1968 PM/PM10 210,000 gal/hr 4.17E‐04 1 87.57 980 0.086 0.376 0.071 0.309 0.000 0.001

CT5N EU041 SV041_E_Admin Cooling Tower 5N 1967 PM/PM10 210,000 gal/hr 4.17E‐04 1 87.57 980 0.086 0.376 0.071 0.309 0.000 0.001

CT4N EU041 SV041_F_Admin Cooling Tower 4N 1962 PM/PM10 210,000 gal/hr 4.17E‐04 1 87.57 980 0.086 0.376 0.071 0.309 0.000 0.001

CT3AN EU041 SV041_G_Admin Cooling Tower 3AN 1962 PM/PM10 210,000 gal/hr 4.17E‐04 1 87.57 980 0.086 0.376 0.071 0.309 0.000 0.001

CT3N EU041 SV041_H_Admin Cooling Tower 3N 1962 PM/PM10 210,000 gal/hr 4.17E‐04 1 87.57 980 0.086 0.376 0.071 0.309 0.000 0.001

CT6ES EU041 SV041_I_Admin Cooling Tower 6ES 1976 PM/PM10 210,000 gal/hr 4.17E‐04 1 87.57 980 0.086 0.376 0.071 0.309 0.000 0.001

CT6S EU041 SV041_J_Admin Cooling Tower 6S 1976 PM/PM10 210,000 gal/hr 4.17E‐04 1 87.57 980 0.086 0.376 0.071 0.309 0.000 0.001

CT5S EU041 SV041_K_Admin Cooling Tower 5S 1962 PM/PM10 210,000 gal/hr 4.17E‐04 1 87.57 980 0.086 0.376 0.071 0.309 0.000 0.001

CT4S EU041 SV041_L_Admin Cooling Tower 4S 1962 PM/PM10 210,000 gal/hr 4.17E‐04 1 87.57 980 0.086 0.376 0.071 0.309 0.000 0.001

CT3AS EU041 SV041_M_Admin Cooling Tower 3AS 1962 PM/PM10 210,000 gal/hr 4.17E‐04 1 87.57 980 0.086 0.376 0.071 0.309 0.000 0.001

CT3S EU041 SV041_N_Admin Cooling Tower 3S 1962 PM/PM10 210,000 gal/hr 4.17E‐04 1 87.57 980 0.086 0.376 0.071 0.309 0.000 0.001

125759 EU041 SV041_O_Admin Cooling Tower 1 1957 PM/PM10 210,000 gal/hr 4.17E‐04 1 87.57 980 0.086 0.376 0.071 0.309 0.000 0.001

CT1WN EU041 SV041_P_Admin Cooling Tower 1WN 1972 PM/PM10 120,000 gal/hr 4.17E‐04 1 50.04 980 0.049 0.215 0.040 0.177 0.000 0.001

152863 EU041 SV041_Q_Admin Cooling Tower 2 1958 PM/PM10 210,000 gal/hr 8.34E‐04 1 175.14 980 0.172 0.752 0.141 0.619 0.001 0.002

CT1WS EU041 SV041_R_Admin Cooling Tower 1WS 1972 PM/PM10 120,000 gal/hr 4.17E‐04 1 50.04 980 0.049 0.215 0.040 0.177 0.000 0.001

New EU041 SV041_S_Admin Cooling Tower New 2004 PM/PM10 360,000 gal/hr 4.17E‐04 1 150.12 980 0.147 0.644 0.121 0.530 0.000 0.002

1.90 8.32 1.56 6.85 0.01 0.03

Insignficant activity under Minn. R. 7007.1300, subp. 3(I)

References:

PM = Water Circulation Rate * Drift Loss * TDS

From: Calculating Realistic PM10 Emissions from Cooling Towers, Joel Reisman and Gordon Frisbie

The drift loss emission factors are therefore calculated as follows

Cooling Tower 2: 1.0 ppm/100 gal (makeup water/recirculating flow) x (1.0 gal drift loss/100 gal makeup water) x 8.34 lb/gal (density of water

Remaining cooling towers: 0.005 gal/100 gal (drift loss/recirculating water) x 8.34 lb/gal (density of water

[3] Actual emissions for Cooling Tower 1 are calculated with the drift eliminator, which was installed in 1998

PM10 fraction of PM emissions (based on information included in the table below): 82.30%

PM2.5 fraction of PM emissions (based on information included in the table below): 0.30%

Detailed calculations illustrating PM10/PM2.5 % by weight.

EPRI Droplet Droplet Particle Solid Solid EPRI % Wgt% PM10 Wgt% PM2.5

Droplet Volume Mass Mass Particle Particle Mass in PM in PM

Diameter (Solids) Volume Diameter Smaller Emissions Emissions

(µm) (µm3) (µg) (µg) (µm3) (µm) (%) (%) (%)

10 524 5.24E‐04 5.13E‐07 0.23 0.764 0.000

20 4189 4.19E‐03 4.11E‐06 1.87 1.527 0.196

30 14137 1.41E‐02 1.39E‐05 6.30 2.291 0.226

40 33510 3.35E‐02 3.28E‐05 14.93 3.055 0.514 0.305

50 65450 6.54E‐02 6.41E‐05 29.15 3.819 1.816

60 113097 1.13E‐01 1.11E‐04 50.38 4.582 5.702

70 179594 1.80E‐01 1.76E‐04 80.00 5.346 21.348

90 381704 3.82E‐01 3.74E‐04 170.03 6.873 49.812

110 696910 6.97E‐01 6.83E‐04 310.44 8.401 70.509

130 1150347 1.15E+00 1.13E‐03 512.43 9.928 82.023

Maximum Rate Emission Factor

(units/hr) (lb/units) (Ref.No.)

[1] The makeup water from evaporation, blowdown, and drift loss from the cooling towers is assumed to be 1 percent of the recirculation water flow. Drift loss is assumed to be 1 percent of the makeup water fo

cooling tower 2 and a maximum of 0.005 percent of the recirculating water for the remaining cooling towers, based on manufacturer's information.

[2] The method used to calculate the maximum emission rate is derived from Section 13.4 of AP‐42, 5th Ed. This section states that a conservatively high PM‐10 emission factor can be obtained by multiplying the tota

liquid drift by the TDS, assuming that once the water evaporates all remaining solid particles are within the PM‐10 size range. The TDS is continuously monitored in the 3M cooling towers and tested approximately

monthly by Nalco. The highest TDS recorded by Nalco was 980 ppm.

H:\3M Admin Offices Maplewood\App\3M Center Admin PTE Calcs - 07 14 14.xlsx.xls[Cooling Towers]

150 1767146 1.77E+00 1.73E‐03 787.18 11.456 88.012 82.304

180 3053628 3.05E+00 2.99E‐03 1360.25 13.747 91.032

210 4849048 4.85E+00 4.75E‐03 2160.03 16.038 92.468

240 7238229 7.24E+00 7.09E‐03 3224.30 18.329 94.091

270 10305995 1.03E+01 1.01E‐02 4590.85 20.620 94.689

300 14137167 1.41E+01 1.39E‐02 6297.47 22.912 96.288

350 22449298 2.24E+01 2.20E‐02 10000.14 26.730 97.011

400 33510322 3.35E+01 3.28E‐02 14927.33 30.549 98.340

450 47712938 4.77E+01 4.68E‐02 21253.95 34.367 99.071

500 65449847 6.54E+01 6.41E‐02 29154.93 38.186 99.071

600 113097336 1.13E+02 1.11E‐01 50379.72 45.823 100.000

TDS: 980 mg/L

Assumptions: water density: 1 g/cm3

particle density: 2.2 g/cm3

Interpolated Results

H:\3M Admin Offices Maplewood\App\3M Center Admin PTE Calcs - 07 14 14.xlsx.xls[Cooling Towers]


Facility Description and CD‐01 Forms

ST. PAUL, MN 55155-4194

Show: Active and Pending Records

Action: PER 004

AQD Facility ID: 12300694

Facility Name:

MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROAD

19 September, 2014 07:30

FACILITY DESCRIPTION: EMISSION UNIT (EU)

MaxFuelInput

(mil Btu)

3M - Administrative Offices - Maplewood

RetiredBy

(Action)

Operator DescriptionID No. EmissionUnit

Status

AddedBy

(Action)

ControlEquip.

ID No(s).

Stack/Vent

ID No(s).

OperatorID

for Item

Insignif-icant

Activity

SICManufacturer ModelNumber

Max.Design

Capacity

MaximumDesign

Capacity

Materials Units n Units d

461 Boiler 1 210-B01EU 001 Active PER 001 SV 001 (M) Hr Heat2672Bros 580I0-56 46 Mmbtu

462 Boiler 1 210-B01EU 001 Removed PER 004 Hr Heat2672Bros 580I0-56 46 Mmbtu

783 Boiler 2 210-B02EU 002 Active PER 001 SV 002 (M) Hr Heat2672Bros 4800-57 78 Mmbtu

784 Boiler 2 210-B02EU 002 Removed PER 004 Hr Heat2672Bros 4800-57 78 Mmbtu

1245 Boiler 3 210-B03EU 003 Active PER 001 SV 003 (M) Hr Heat2672Bros W4-1725-825 124 Mmbtu

1246 Boiler 3 210-B03 - BoilerEU 003 Active PER 004 SV 003 (M) 2672Bros W4-1725-825

1847 Boiler 4 210-B04EU 004 Active PER 001 SV 004 (M) Hr Heat2672Bros DGO-152 184 Mmbtu

1848 Boiler 4 210-B04 - BoilerEU 004 Active PER 004 SV 004 (M) 2672Bros DGO-152

1849 Boiler 5 210-B05EU 005 Active PER 001 SV 005 (M) Hr Heat2672Riley/Bros DGO-152 184 Mmbtu

18410 Boiler 5 210-B05 - BoilerEU 005 Active PER 004 SV 005 (M) 2672Riley/Bros DGO-152

21911 Boiler 6 210-B06EU 006 Active PER 001 CE 001SV 006 (M) Hr Heat2672Nebraska N2S-8/5-90 219 Mmbtu

21912 Boiler 6 210-B06 - BoilerEU 006 Active PER 004 CE 001SV 006 (M) 2672Nebraska N2S-8/5-90

13 Gasoline Generator 338820EU 007 Removed PER 001 2672Removed 2000

14 NG Generator 201-731417EU 008 Active PER 001 SV 008 (M) Energy2672Onan 115.0 WA-15R27198L 75 Kw

15 NG Generator 201 -Reciprocating IC Engine

EU 008 Active PER 004 SV 008 (M) Energy2672Onan 115.0 WA-15R27198L 80 Kw

16 NG Generator 205-821913EU 009 Active PER 001 SV 009 (M) Energy2672Kohler 80R272 PA-187341-72N 75 Kw


EU 009 Active PER 004 SV 009 (M) Energy2672Kohler 80R272 PA-187341-72N 80 Kw

18 NG Generator 209-734566EU 010 Active PER 001 SV 010 (M) Energy2672Onan 45EF-4XR/13E 40 Kw


EU 010 Active PER 004 SV 010 (M) Energy2672Onan 45EF-4XR/13E 40 Kw

20 NG Generator 209-EG0001EU 011 Removed PER 001 2672Removed 2000

21 NG Generator 210-296269EU 012 Active PER 001 SV 012 (M) Energy2672Katolight N150/170MRE4E 150 Kw

22 NG Generator 210-296269EU 012 Removed PER 004 Energy2672Katolight N150/170MRE4E 150 Kw

23 NG Generator 216-168605EU 013 Active PER 001 SV 013 (M) Energy2672Onan 40EF-4R8-45C 40 Kw

24 NG Generator 216-168605EU 013 Removed PER 004 Energy2672Onan 40EF-4R8-45C 40 Kw

25 Fire Pump 217-00001EU 014 Active PER 001 SV 014 (M) Energy2672Fairbanks Morse 6 Nozzles 4 Stage 78.3 Kw

Page 1 of 5 (a)

19 September, 2014 07:30


ID No. ElevatorType

BottleneckPct.Fuel/

SpaceHeat

Firing MethodAddedBy

(Action)

RemovalDate

InitialStartup

Date

Comm-ence

Const.Date

EmissionUnit

Status

1 EU 001 60PER 001 01/01/195601/01/1956Active

2 EU 001 60PER 004 02/01/200601/01/195601/01/1956Removed

3 EU 002 60PER 001 01/01/195701/01/1957Active

4 EU 002 60PER 004 02/01/200601/01/195701/01/1957Removed

5 EU 003 60PER 001 01/01/196001/01/1960Active

6 EU 003 60PER 004 01/01/196001/01/1960Active

7 EU 004 60PER 001 01/01/196401/01/1964Active

8 EU 004 60PER 004 01/01/196401/01/1964Active

9 EU 005 60PER 001 01/01/197201/01/1972Active

10 EU 005 60PER 004 01/01/197201/01/1972Active

11 EU 006 60PER 001 01/01/199201/01/1992Active

12 EU 006 60PER 004 01/01/199201/01/1992Active

13 EU 007 PER 001 01/01/2000Removed

14 EU 008 PER 001 07/01/198407/01/1984Active

15 EU 008 PER 004 07/01/198407/01/1984Active

16 EU 009 PER 001 07/01/199607/01/1996Active

17 EU 009 PER 004 07/01/199607/01/1996Active

18 EU 010 PER 001 06/01/196706/01/1967Active

19 EU 010 PER 004 06/01/196706/01/1967Active

20 EU 011 PER 001 01/01/2000Removed

21 EU 012 PER 001 05/01/196205/01/1962Active

22 EU 012 PER 004 12/31/201205/01/196205/01/1962Removed

23 EU 013 PER 001 05/01/196105/01/1961Active

24 EU 013 PER 004 12/31/200805/01/196105/01/1961Removed

25 EU 014 PER 001 01/01/196001/01/1960Active

Page 1 of 5 (b)

ST. PAUL, MN 55155-4194


Action: PER 004


Facility Name:


19 September, 2014 07:30


MaxFuelInput

(mil Btu)


RetiredBy

(Action)


Status

AddedBy

(Action)

ControlEquip.

ID No(s).

Stack/Vent

ID No(s).

OperatorID

for Item

Insignif-icant

Activity


Max.Design

Capacity

MaximumDesign

Capacity


26 Fire Pump 217-00001EU 014 Removed PER 004 Energy2672Fairbanks Morse 6 Nozzles 4 Stage 78.3 Kw

27 NG Generator 218-321528EU 015 Active PER 001 SV 015 (M) Energy2672Onan 115WA-4XR8-1933E 100 Kw

28 NG Generator 218-321528EU 015 Removed PER 004 Energy2672Onan 115WA-4XR8-1933E 100 Kw

29 NG Generator 230-427957EU 016 Active PER 001 SV 016 (M) Energy2672Onan 175.0 WB-15R R13J 175 Kw


EU 016 Active PER 004 SV 016 (M) Energy2672Onan 175.0 WB-15R R13J 175 Kw

31 NG Generator 235-734565EU 017 Removed PER 001 2672Removed 1997

32 NG Generator 235-EG0001EU 018 Active PER 001 SV 018 (M) Energy2672Stamford VC I 274 H1 140 Kw


EU 018 Active PER 004 SV 018 (M) Energy2672Stamford VC I 274 H1 140 Kw



36 NG Generator 236-EG0001EU 021 Active PER 001 SV 021 (M) Energy2672Kohler 180 RDZ Liquid Cooled 180 Kw


EU 021 Active PER 004 SV 021 (M) Energy2672Kohler 180 RDZ Liquid Cooled 180 Kw

38 Diesel Generator 217-494480EU 022 Active PER 001 SV 022 (M) Energy2672Cummings 680FDR7026CCW 450 Kw

39 Diesel Generator 217-494480EU 022 Removed PER 004 Energy2672Cummings 680FDR7026CCW 450 Kw

40 Diesel Generator 220-293964EU 023 Active PER 001 SV 023 (M) Energy2672Onan 230DWF-4XR8-5511F 230 Kw

41 Diesel Generator 220-293964EU 023 Removed PER 004 Energy2672Onan 230DWF-4XR8-5511F 230 Kw

42 Diesel Generator 220-293965EU 024 Active PER 001 SV 024 (M) Energy2672Onan 230DWF-4XR8-5511F 230 Kw

43 Diesel Generator 220-293965EU 024 Removed PER 004 Energy2672Onan 230DWF-4XR8-5511F 230 Kw

44 Diesel Generator 223-427829EU 025 Active PER 001 SV 025 (M) Energy2672Onan 250.0 DYB-4XR133360 312 Kw

45 Diesel Generator 223 -Reciprocating IC Engine

EU 025 Active PER 004 Energy2672Onan 250.0 DYB-4XR133360 312 Kw

46 Diesel Generator 224-313600EU 026 Active PER 001 SV 026 (M) Energy2672Onan 400DFV-4XR8-2387B 400 Kw

47 Diesel Generator 224-313600EU 026 Removed PER 004 Energy2672Onan 400DFV-4XR8-2387B 400 Kw

48 Diesel Generator 224-592212EU 027 Active PER 001 SV 027 (M) Energy2672Marathon 572RSL2032AL000W 400 Kw


EU 027 Active PER 004 SV 027 (M) Energy2672Marathon 572RSL2032AL000W 400 Kw

50 Diesel Generator 277-EG0001EU 028 Active PER 001 SV 028 (M) Energy2672Kohler Power Systems 900R0ZD-4 800 Kw

Page 2 of 5 (a)

19 September, 2014 07:30


ID No. ElevatorType

BottleneckPct.Fuel/

SpaceHeat


(Action)

RemovalDate

InitialStartup

Date

Comm-ence

Const.Date

EmissionUnit

Status

26 EU 014 PER 004 12/31/200801/01/196001/01/1960Removed

27 EU 015 PER 001 01/01/196901/01/1969Active

28 EU 015 PER 004 12/31/201001/01/196901/01/1969Removed

29 EU 016 PER 001 09/01/197309/01/1973Active

30 EU 016 PER 004 09/01/197309/01/1973Active

31 EU 017 PER 001 01/01/1997Removed

32 EU 018 PER 001 08/01/199608/01/1996Active

33 EU 018 PER 004 08/01/199608/01/1996Active

34 EU 019 PER 001 01/01/2000Removed

35 EU 020 PER 001 01/01/2000Removed

36 EU 021 PER 001 11/01/200011/01/2000Active

37 EU 021 PER 004 11/01/200011/01/2000Active

38 EU 022 PER 001 10/01/198010/01/1980Active

39 EU 022 PER 004 10/01/198010/01/1980Removed

40 EU 023 PER 001 01/01/196701/01/1967Active

41 EU 023 PER 004 07/01/200701/01/196701/01/1967Removed

42 EU 024 PER 001 01/01/196701/01/1967Active

43 EU 024 PER 004 07/01/200701/01/196701/01/1967Removed

44 EU 025 PER 001 01/01/196901/01/1969Active

45 EU 025 PER 004 01/01/196901/01/1969Active

46 EU 026 PER 001 01/01/196901/01/1969Active

47 EU 026 PER 004 01/01/196901/01/1969Removed

48 EU 027 PER 001 01/01/198901/01/1989Active

49 EU 027 PER 004 01/01/198901/01/1989Active

50 EU 028 PER 001 06/23/200305/01/2003Active

Page 2 of 5 (b)

ST. PAUL, MN 55155-4194


Action: PER 004


Facility Name:


19 September, 2014 07:30


MaxFuelInput

(mil Btu)


RetiredBy

(Action)


Status

AddedBy

(Action)

ControlEquip.

ID No(s).

Stack/Vent

ID No(s).

OperatorID

for Item

Insignif-icant

Activity


Max.Design

Capacity

MaximumDesign

Capacity



EU 028 Active PER 004 SV 028 (M) Energy2672Kohler Power Systems 900R0ZD-4 800 Kw







56 Diesel Generator 225-496643EU 031 Active PER 001 SV 031 (M) Energy2672Onan 150.0 DYG15R18940G 150 Kw


EU 031 Active PER 004 SV 031 (M) Energy2672Onan 150.0 DYG15R18940G 150 Kw

58 Diesel Generator 5243-512084

EU 032 Active PER 001 SV 032 (M) Energy2672Marathon 680FDR8064AB-P587W 600 Kw












EU 035 Active PER 001 SV 035 (M) Energy2672Marathon 680FDR8064GG-P500W 600 Kw







68 Diesel Generator 251-426692EU 037 Active PER 001 SV 037 (M) Energy2672Onan 400.0 DFV-4XR/15823E 400 Kw


EU 037 Active PER 004 SV 037 (M) Energy2672Onan 400.0 DFV-4XR/15823E 400 Kw

70 Diesel Generator 260-469589EU 038 Active PER 001 SV 038 (M) Energy2672Onan 500.0 DFY 4XR15819A 500 Kw

Page 3 of 5 (a)

19 September, 2014 07:30


ID No. ElevatorType

BottleneckPct.Fuel/

SpaceHeat


(Action)

RemovalDate

InitialStartup

Date

Comm-ence

Const.Date

EmissionUnit

Status

51 EU 028 PER 004 06/23/200305/01/2003Active

52 EU 029 PER 001 06/23/200305/01/2003Active

53 EU 029 PER 004 06/23/200305/01/2003Active

54 EU 030 PER 001 06/23/200305/01/2003Active

55 EU 030 PER 004 06/23/200305/01/2003Active

56 EU 031 PER 001 03/01/198003/01/1980Active

57 EU 031 PER 004 03/01/198003/01/1980Active

58 EU 032 PER 001 06/01/198006/01/1980Active

59 EU 032 PER 004 06/01/198006/01/1980Active

60 EU 033 PER 001 06/01/198006/01/1980Active

61 EU 033 PER 004 06/01/198006/01/1980Active

62 EU 034 PER 001 06/01/198006/01/1980Active

63 EU 034 PER 004 06/01/198006/01/1980Active

64 EU 035 PER 001 04/01/198504/01/1985Active

65 EU 035 PER 004 04/01/198504/01/1985Active

66 EU 036 PER 001 04/01/198504/01/1985Active

67 EU 036 PER 004 04/01/198504/01/1985Active

68 EU 037 PER 001 11/01/197511/01/1975Active

69 EU 037 PER 004 11/01/197511/01/1975Active

70 EU 038 PER 001 01/01/197601/01/1976Active

Page 3 of 5 (b)

ST. PAUL, MN 55155-4194


Action: PER 004


Facility Name:


19 September, 2014 07:30


MaxFuelInput

(mil Btu)


RetiredBy

(Action)


Status

AddedBy

(Action)

ControlEquip.

ID No(s).

Stack/Vent

ID No(s).

OperatorID

for Item

Insignif-icant

Activity


Max.Design

Capacity

MaximumDesign

Capacity



EU 038 Active PER 004 SV 038 (M) Energy2672Onan 500.0 DFY 4XR15819A 500 Kw

72 Diesel Generator 270-496687EU 039 Active PER 001 SV 039 (M) Energy2672Marathon 680FDR8068AB-P051W 600 Kw



74 Diesel Generator 275-627516EU 040 Active PER 001 SV 040 (M) Energy2672Caterpillar 3508-D1 750 Kw


EU 040 Active PER 004 SV 040 (M) Energy2672Caterpillar 3508-D1 750 Kw

76 Cooling Towers (InsignificantActivity)

EU 041 Active PER 001 SV 041 (M) 2672NA NA

77 Cooling Towers (InsignificantActivity)

EU 041 Removed PER 004 2672NA NA

78 New Boiler 2EU 042 Retired PER 002 Hr Heat2672TBD TBD 94 Mmbtu

79 New Boiler 2EU 042 Removed PER 004 Hr Heat2672TBD TBD 94 Mmbtu

21980 Boiler No. 7EU 043 Active PER 002 CE 002SV 043 (M) Hr Heat2672TBD TBD 219 Mmbtu

21981 Boiler No. 7 - BoilerEU 043 Active PER 004 CE 002SV 043 (M) 2672Rentech V8551GOXXX

2.0082 NG Boiler 278EU 044 Active PER 003 SV 044 (M) Hr Heat2672TBD TBD 2.00 Mmbtu

2.0083 NG Boiler 278 - BoilerEU 044 Active PER 004 SV 044 (M) 2672Mestek HydraTherm Model KN-





.25688 Diesel Generator 278EU 047 Active PER 003 SV 047 (M) Hr Heat2672TBD TBD .256 Mmbtu

.25689 Diesel Generator 278 -Reciprocating IC Engine

EU 047 Active PER 004 SV 047 (M) 2672Caterpillar D80P4

90 Emergency Generator #1 Bldg220 - Reciprocating IC Engine

EU 048 Active PER 004 SV 048 (M) Energy8731Cummins DQDAA-5858152 250 Kw

91 Emergency Generator #2 Bldg220 - Reciprocating IC Engine

EU 049 Active PER 004 SV 049 (M) Energy8731Cummins DQDAA-5857344 250 Kw

92 Diesel Fire Pump Bldg 217 -Reciprocating IC Engine

EU 050 Active PER 004 SV 050 (M) Energy8731Clarke JU6H-UF30 160 Hp

93 Emergency Generator Bldg217 - Reciprocating IC Engine

EU 051 Active PER 004 SV 051 (M) Energy8731Caterpillar C15 ATAAC 450 Kw

Page 4 of 5 (a)

19 September, 2014 07:30


ID No. ElevatorType

BottleneckPct.Fuel/

SpaceHeat


(Action)

RemovalDate

InitialStartup

Date

Comm-ence

Const.Date

EmissionUnit

Status

71 EU 038 PER 004 01/01/197601/01/1976Active

72 EU 039 PER 001 01/01/198101/01/1981Active

73 EU 039 PER 004 01/01/198101/01/1981Active

74 EU 040 PER 001 12/01/199012/01/1990Active

75 EU 040 PER 004 12/01/199012/01/1990Active

76 EU 041 PER 001Active

77 EU 041 PER 004Removed

78 EU 042 60PER 002Retired

79 EU 042 60PER 004Removed

80 EU 043 90PER 002 01/01/200501/01/2005Active

81 EU 043 90PER 004 01/01/200601/01/2006Active


83 EU 044 PER 004 01/01/200601/01/2006Active


85 EU 045 PER 004 01/01/200601/01/2006Active


87 EU 046 PER 004 01/01/200601/01/2006Active


89 EU 047 PER 004 05/01/200612/31/2005Active

90 EU 048 PER 004 07/01/200707/01/2007Active

91 EU 049 PER 004 07/01/200707/01/2007Active

92 EU 050 PER 004 01/01/200801/01/2008Active

93 EU 051 PER 004 05/17/201004/15/2010Active

Page 4 of 5 (b)

ST. PAUL, MN 55155-4194


Action: PER 004


Facility Name:


19 September, 2014 07:30


MaxFuelInput

(mil Btu)


RetiredBy

(Action)


Status

AddedBy

(Action)

ControlEquip.

ID No(s).

Stack/Vent

ID No(s).

OperatorID

for Item

Insignif-icant

Activity


Max.Design

Capacity

MaximumDesign

Capacity



EU 052 Active PER 004 SV 052 (M) Energy8731Kohler 125RGZ 125 Kw


EU 053 Active PER 004 SV 053 (M) Energy8731Kohler GM28341 125 Kw

96 EU012 ReplacementGenerator - Reciprocating ICEngine

EU 054 Active PER 004 SV 012 (M) Energy8731Cummins DFEJ-105678965 603 Hp

7.0497 Diesel Emergency GeneratorBldg 280 - Reciprocating ICEngine

EU 055 Active PER 004 CE 003SV 055 (M) Energy8731Detroit Diesel 750-XC6DT2 750 Kw

Page 5 of 5 (a)

19 September, 2014 07:30


ID No. ElevatorType

BottleneckPct.Fuel/

SpaceHeat


(Action)

RemovalDate

InitialStartup

Date

Comm-ence

Const.Date

EmissionUnit

Status

94 EU 052 PER 004 11/01/200811/01/2008Active

95 EU 053 PER 004 01/01/201001/01/2010Active

96 EU 054 PER 004 01/01/201201/01/2012Active

97 EU 055 PER 004 12/01/2014Active

Page 5 of 5 (b)

MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194


Action: PER 004


Facility Name: 3M - Administrative Offices - Maplewood

19 September, 2014 07:29

FACILITY DESCRIPTION: STACK/VENTS (SV)

ID No. Discharge DirectionFlow Rate/Temperature

Information Source

Exit GasTemperature

at Top(ºF)

DesignFlow Rate

at Top(ACFM)

Width(feet)

Diameteror Length

(feet)

Inside DimensionsHeight ofOpening

FromGround(feet)

AddedBy

(Action)

RetiredBy

(Action)

OperatorID

for Item

Operators DescriptionStack/Vent

Status

1 SV 001 Up, No CapManufacturer620181253.7105.75PER 001 Boiler 1 210-B01Active

2 SV 001 Up, No CapManufacturer620181253.7105.75PER 004 Boiler 1 210-B01Removed


4 SV 002 Up, No CapManufacturer620307344.2105.75PER 004 Boiler 2 210-B02Removed

5 SV 003 Up, No CapManufacturer300341005105.75PER 001 Boiler 3 210-B03Active








13 SV 007 PER 001 Gasoline Generator 338820Active

14 SV 007 PER 004 Gasoline Generator 338820Removed

15 SV 008 HorizontalEstimate4007450.4210PER 001 NG Generator 201-731417Active



18 SV 010 HorizontalEstimate4006000.252.5PER 001 NG Generator 209-734566Active

19 SV 010 Up, No CapEstimate4002250.332.5PER 004 NG Generator 209-734566Active

20 SV 011 PER 001 NG Generator 209-EG0001Active

21 SV 011 PER 004 NG Generator 209-EG0001Removed

22 SV 012 Up, No CapEstimate4008000.4230PER 001 NG Generator 210-296269Active




26 SV 014 Up, No CapEstimate40012000.4214PER 001 Fire Pump 217-00001Active

27 SV 014 Up, No CapEstimate40012400.4214PER 004 Fire Pump 217-00001Active

Page 1 of 4



Action: PER 004



19 September, 2014 07:29



Information Source

Exit GasTemperature

at Top(ºF)

DesignFlow Rate

at Top(ACFM)

Width(feet)

Diameteror Length

(feet)


FromGround(feet)

AddedBy

(Action)

RetiredBy

(Action)

OperatorID

for Item


Status





32 SV 017 PER 001 NG Generator 235-734565Active

33 SV 017 PER 004 NG Generator 235-734565Removed

34 SV 018 DownEstimate4008000.545PER 001 NG Generator 235-EG0001Active

35 SV 018 Up, No CapEstimate4007750.545PER 004 NG Generator 235-EG0001Active





40 SV 021 Up, No CapManufacturer13008540.678PER 001 NG Generator 236-EG0001Active

41 SV 021 Up, No CapManufacturer4008200.6720PER 004 NG Generator 236-EG0001Active

42 SV 022 Up, No CapEstimate40025700.4214PER 001 Diesel Generator 217-494480Active



45 SV 023 Up, No CapEstimate40015150.423PER 004 Diesel Generator 220-293964Removed


47 SV 024 Up, No CapEstimate40015150.423PER 004 Diesel Generator 220-293965Removed

48 SV 025 HorizontalEstimate40024350.670PER 001 Diesel Generator 223-427829Active






54 SV 028 Up, No CapManufacturer8007360129PER 001 Diesel Generator 277-EG0001Active

Page 2 of 4



Action: PER 004



19 September, 2014 07:29



Information Source

Exit GasTemperature

at Top(ºF)

DesignFlow Rate

at Top(ACFM)

Width(feet)

Diameteror Length

(feet)


FromGround(feet)

AddedBy

(Action)

RetiredBy

(Action)

OperatorID

for Item


Status

55 SV 028 Up, No CapManufacturer8807110122.5PER 004 Diesel Generator 277-EG0001Active







62 SV 032 HorizontalEstimate40042050.6712PER 001 Diesel Generator 5 243-512084Active

63 SV 032 Up, No CapEstimate40040000.6712PER 004 Diesel Generator 5 243-512084Active

















80 SV 041 PER 001 Cooling Towers - Insignificant ActivityActive

81 SV 041 PER 004 Cooling Towers - Insignificant ActivityRemoved

Page 3 of 4



Action: PER 004



19 September, 2014 07:29



Information Source

Exit GasTemperature

at Top(ºF)

DesignFlow Rate

at Top(ACFM)

Width(feet)

Diameteror Length

(feet)


FromGround(feet)

AddedBy

(Action)

RetiredBy

(Action)

OperatorID

for Item


Status

82 SV 042 Up, No CapManufacturer300265274.2105.75PER 001 New Boiler 2Active

83 SV 043 Up, No CapEstimate354720726.0100.0PER 002 049 Boiler 7, 210-B07 [1]Active

84 SV 043 Up, No CapEstimate354691006.0100.0PER 004 049 Boiler 7, 210-B07 [1]Active

85 SV 044 PER 003 NG Boiler 278Active

86 SV 044 Up, No CapEstimate80444127PER 004 NG Boiler 278Active





91 SV 047 PER 003 Diesel Generator 278Active

92 SV 047 Up, No CapEstimate4007810.25999PER 004 Diesel Generator Bldg 278Active

93 SV 048 Up, No CapEstimate40020850.423PER 004 Diesel Generator # 1 Bldg 220Active

94 SV 049 Up, No CapEstimate40020850.423PER 004 Diesel Generator # 2 Bldg 220Active

95 SV 050 Up, No CapEstimate4009530.4214PER 004 Diesel Fire Pump Bldg 217Active

96 SV 051 Up, No CapEstimate40026520.421009PER 004 Emergency Generator Bldg 217Active



99 SV 054 Up, No CapEstimate4008250.421064PER 004 EU 012 Emergency Generator Bldg 210Active

100 SV 055 Up, No CapEstimate400825PER 004 Emergency Generator Bldg 217Active

Page 4 of 4



Action: PER 004



19 September, 2014 07:29

FACILITY DESCRIPTION: CONTROL EQUIPMENT (CE)

ID No. AddedBy

(Action)

RetiredBy

(Action)

OperatorID

for Item

Control

Equip.Type

Control Equipment Description ModelControlEquip.Status

Manufacturer PollutantsControlled

AfterburnerCombustionParameters

CaptureEfficiency

(%)

Destruction/CollectionEfficiency

(%)

1 CE 001 PER 001 026 Flue Gas Recirculation 695DAF42Active Coen NOx 0 0

2 CE 002 PER 002 026 Flue Gas Recirculation TBDActive TBD NOx

3 CE 002 PER 004 026 Flue Gas RecirculationActive NA NOx

4 CE 003 PER 004 099 Diesel Particulate Filter PM Clarity 750 SystemActive ELM Energy, LLC COPM2.5PM10PM

100100100100

90858585

Page 1 of 1


Show:

Action:

AQD Facility ID:

Facility Name:

Pending Records Only

PER 004

12300694


FACILITY DESCRIPTION: GROUPS (GP)

19 September, 2014 07:28

ID No. AddedBy

(Action)

RetiredBy

(Action)

Includein EI

OperatorID

for Item

Group Description Group ItemsGroupStatus

1 GP 001 PER 004 Existing, SI, <= 500 Hp, Emergency Engines EU 008, EU 009, EU 010, EU 016, EU 018, EU 021Active

2 GP 002 PER 004 Existing, CI, > 500 Hp, Emergency Engines EU 027, EU 032, EU 033, EU 034, EU 035, EU 036, EU 037, EU 038, EU 039,EU 040

Active

3 GP 003 PER 004 Existing, CI, <= 500 Hp, Emergency Engines EU 025, EU 031, EU 047Active

4 GP 004 PER 004 New, CI > 500 Hp, Emergency Engines EU 028, EU 029, EU 030, EU 051, EU 054, EU 055Active

5 GP 005 PER 004 New, <= 500 Hp, Emergency Engines EU 048, EU 049, EU 050, EU 052, EU 053Active

6 GP 006 PER 004 Building 243 Engines EU 032, EU 033, EU 034, EU 035, EU 036Active

7 GP 007 PER 004 Natural Gas Emergency Generators EU 008, EU 009, EU 010, EU 016, EU 018, EU 021, EU 052, EU 053Active

8 GP 008 PER 004 Diesel Generators < 600 Hp EU 025, EU 027, EU 031, EU 037, EU 047, EU 048, EU 049Active

9 GP 009 PER 004 Diesel Generators > 600 Hp EU 028, EU 029, EU 030, EU 032, EU 033, EU 034, EU 035, EU 036, EU 038,EU 039, EU 040, EU 051, EU 054, EU 055

Active

10 GP 010 PER 004 Bldg 278 NG Boilers EU 044, EU 045, EU 046Active

11 GP 011 PER 004 Best Management Practices for Emergency Engines EU 008, EU 009, EU 010, EU 016, EU 018, EU 021, EU 025, EU 027, EU 028,EU 029, EU 030, EU 031, EU 032, EU 033, EU 034, EU 035, EU 036, EU 037,EU 038, EU 039, EU 040, EU 047, EU 048, EU 049, EU 050, EU 051, EU 052,EU 053, EU 054, EU 055

Active

12 GP 012 PER 004 CEMS and COMS - NSPS Db EU 006, EU 043, MR 001, MR 002, MR 003, MR 004, MR 005, MR 006, MR007, SV 006, SV 043

Active

Page 1 of 1

Insignif-icant

Activity

OperatorID

for Item



Action: PER 004



19 September, 2014 07:30

FACILITY DESCRIPTION: STORAGE TANKS (TK)

ID No. Capacity(1000 gal)

InteriorHeight

(ft.)

InteriorDiameter

(ft.)

AddedBy

(Action)

Construction TypeTankStatus

Product StoredControlEquip.

ID No(s).

RetiredBy

(Action)

1 TK 001 50.0060.0 12.0 Fixed RoofActive PER 001 No 2 Very Low Sulfur Fuel Oil

2 TK 001 50.0060.0 12.0 Fixed RoofRemoved PER 004 No 2 Very Low Sulfur Fuel Oil

3 TK 002 10.0027.0 8.00 UndergroundActive PER 001 Gasoline (Unleaded)

4 TK 003 20.0028.0 11.0 UndergroundActive PER 001 Gasoline (Unleaded)

5 TK 004 50.0060.0 12.0 Fixed RoofActive PER 001 No 2 Very Low Sulfur Fuel Oil

6 TK 004 Removed PER 004 Never Installed

7 TK 005 10.00 Fixed RoofActive PER 001 Diesel Fuel

8 TK 005 Removed PER 004 Never Installed

9 TK 006 15.0021.0 11.0 UndergroundActive PER 001 No 2 Very Low Sulfur Fuel Oil

10 TK 006 600.0028.0 57.0 Fixed RoofActive PER 004 No. 6 Fuel Oil and No. 2 Fuel Oil (very low sulfur)

11 TK 007 600.0028.0 57.0 Fixed RoofActive PER 004 No. 2 Fuel Oil (very low sulfur)

Page 1 of 1 (a)

ID No.

FACILITY DESCRIPTION: STORAGE TANKS (TK)

19 September, 2014 07:30

YearRemoved

YearInstalled

Seal Type(floating roof only)

AddedBy

(Action)

Support Type(floating roof only)

ColumnCount

ColumnDiameter

(ft.)

Deck Type(floating roof only)

TankStatus

1 TK 001 1993PER 001Active

2 TK 001 20141993PER 004Removed



5 TK 004 PER 001Active

6 TK 004 PER 004Removed

7 TK 005 PER 001Active

8 TK 005 PER 004Removed




Page 1 of 1 (b)



Action: PER 004



19 September, 2014 07:31 19 September, 2014 07:31

FACILITY DESCRIPTION: CONTINUOUS MONITORING SYSTEMS (CM)

ID No. AddedBy

(Action)

RetiredBy

(Action)

MonitorID No(s).

DASID No(s).

OperatorID

for Item

CMS Description Parameter Month/Year

Installed

Month/Year

Removed

Cert.Date

Cert.Basis

CMSStatus

1 CM 001 PER 001 MR 001 DA 001DA 002

Boiler 6 NOx Nitrogen Oxides 11/09/1993 40CFR60Active

2 CM 002 PER 001 MR 002 DA 001DA 002

Boiler 6 Opacity Opacity 12/13/1993 40CFR60Active

3 CM 003 PER 001 MR 003 DA 001DA 002

Boiler 6 Diluent O2 Oxygen 11/09/1993 40CFR60Active

Page 1 of 1

MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY

19 September, 2014 07:30

520 LAFAYETTE ROADST. PAUL, MN 55155-4194 FACILITY DESCRIPTION: DATA ACQUISITION SYSTEMS (DA)


Action: PER 004



ID No. RemovalDate

InstallationDate

Data StorageMedium

Serial NumberManufacturer Model NumberDASStatus

OperatorID

for Item

Data Acquisition System DescriptionRetiredBy

(Action)

AddedBy

(Action)

1 DA 001 Electronic05377EVTaxan MV875Active Boiler 6 PrimaryPER 001

2 DA 002 Paper TapeNoneYokogawa YEWActive Boiler 6 BackupPER 001

3 DA 001 01/01/2002Electronic05377EVTaxan MV875Active Boiler 6 PrimaryPER 004

4 DA 002 01/01/2002Paper TapeNoneYokogawa YEWActive Boiler 6 BackupPER 004

Page 1 of 1



Action: PER 004



19 September, 2014 07:30

FACILITY DESCRIPTION: CONTINUOUS MONITORS (MR)

ParametersMonitored

Serial NumberID No. Model NumberManufacturerOperatorID

for Item

MonitoredItem

(ID No(s).)

RetiredBy

(Action)

AddedBy

(Action)

Monitor DescriptionMonitorStatus

1 NOx0232373RMR 001 SM8100ALear SieglerBoiler 6SV 006PER 001 NOxActive

2 NOxNO0173MR 001 TML41M02TeledyneBoiler 6SV 006PER 004 NOxActive

3 OpacityMC2000-0188MR 002 DynatronLear SieglerBoiler 6SV 006PER 001 OpacityActive

4 Opacity5601148MR 002 ML560TeledyneBoiler 6SV 006PER 004 OpacityActive

5 O2JJ113LA450MR 003 OXY-ANAJohnson-YokogawaBoiler 6SV 006PER 001 Diluent O2Active

6 O2NO0173MR 003 TML41M02TeledyneBoiler 6SV 006PER 004 Diluent O2Active

7 NOxMR 004 SM8175Lear SieglerBoiler 7SV 043PER 002 NOxActive

8 NOxNOx

252MR 004 T200MTeledyneBoiler 7SV 043PER 004 NOxActive

9 COMR 005 Teledyne Monitor LabsBoiler 7SV 043PER 002 COActive

10 COCO

CO993MR 005 TLM30TeledyneBoiler 7SV 043PER 004 COActive

11 OpacityMR 006 560Light HawkBoiler 7SV 043PER 002 OpacityActive

12 OpacityOpacity

5601149MR 006 560Teledyne LightHawkBoiler 7SV 043PER 004 OpacityActive

13 O2MR 007 LS420Lear SieglerBoiler 7SV 043PER 002 Diluent O2Active

14 O2O2

252MR 007 T200MTeledyneBoiler 7SV 043PER 004 Diluent O2Active

Page 1 of 1 (a)

19 September, 2014 07:30

FACILITY DESCRIPTION: CONTINUOUS MONITORS (MR)

ID No. AddedBy

(Action)

SpanValue

SystemFull-

ScaleValue

BypassCapa-bility?

RemovalDate

InstallationDate

OpticalPath

LengthRatio

MonitorStatus

1 MR 001 PER 001 208 208 No 02/01/1993Active

2 MR 001 PER 004 208 208 No 02/01/1993Active

3 MR 002 PER 001 1000 1000 No 1Active

4 MR 002 PER 004 1000 1000 No 10/15/20061Active

5 MR 003 PER 001 2500 1000 NoActive

6 MR 003 PER 004 2500 1000 No 10/15/2006Active

7 MR 004 PER 002 NoActive

8 MR 004 PER 004200 200

No 10/15/2006Active


10 MR 005 PER 004500 500

No 10/15/2006Active


12 MR 006 PER 00425 25

No 10/15/2006Active


14 MR 007 PER 00425 25

No 10/15/2006Active

Page 1 of 1 (b)

19 September, 2014 07:31


FACILITY DESCRIPTION: Potential-to-emit (by pollutant)

RetiredBy

(Action)

AddedBy

(Action)

ItemPollutant ActualEmissions

(tons per yr)

LimitedPotential

(tons per yr)

UnrestrictedPotential

(tons per yr)

HourlyPotential

(lbs per hr)




Acetaldehyde

PER 004GP 007 7.300E-02 1.830E-02 1.830E-02

PER 004GP 008 1.370E-02 3.430E-03 3.430E-03

PER 004GP 009 1.320E-04 3.300E-06 3.300E-06

Totals 2.173E-02 2.173E-02 0.000E+00

Acrolein

PER 004GP 007 7.320E-02 1.830E-02 1.830E-02

PER 004GP 008 1.660E-03 4.140E-04 4.140E-04

PER 004GP 009 4.130E-06 1.030E-06 1.030E-06

Totals 1.872E-02 1.872E-02 0.000E+00

Benzene

PER 004EU 003 2.550E-04 1.120E-03 1.120E-03

PER 004EU 004 3.790E-04 1.660E-03 1.660E-03

PER 004EU 005 3.790E-04 1.660E-03 1.660E-03

PER 004EU 006 4.510E-04 1.970E-03 1.970E-03

PER 004EU 043 4.510E-04 1.970E-03 1.970E-03

PER 004GP 007 1.830E-02 4.560E-03 4.560E-03

PER 004GP 008 1.670E-02 4.180E-03 4.180E-03

PER 004GP 009 4.060E-04 1.020E-04 1.020E-04

PER 004GP 010 1.240E-05 5.410E-05 5.410E-05

Totals 1.728E-02 1.728E-02 0.000E+00

Arsenic compounds

PER 004EU 003 4.960E-04 2.170E-03 2.170E-03

PER 004EU 004 7.360E-04 3.220E-03 3.220E-03

PER 004EU 005 7.360E-04 3.220E-03 3.220E-03

PER 004EU 006 8.760E-04 3.010E-04 3.010E-04

PER 004EU 043 8.760E-04 2.760E-03 2.760E-03

PER 004GP 010 1.180E-06 5.150E-06 5.150E-06

Totals 1.168E-02 1.168E-02 0.000E+00

Biphenyl

PER 004GP 007 3.720E-05 9.290E-06 9.290E-06

Totals 0.000E+00 0.000E+00 0.000E+00

1,3-Butadiene

PER 004GP 007 7.720E-03 1.930E-03 1.930E-03

PER 004GP 008 7.000E-04 1.750E-04 1.750E-04

Totals 2.105E-03 2.105E-03 0.000E+00

Page 1 of 17

19 September, 2014 07:31



RetiredBy

(Action)

AddedBy

(Action)


(tons per yr)

LimitedPotential

(tons per yr)


(tons per yr)

HourlyPotential

(lbs per hr)




Beryllium

PER 004EU 003 3.720E-04 1.630E-03 1.630E-03

PER 004EU 004 5.520E-04 2.420E-03 2.420E-03

PER 004EU 005 5.520E-04 2.420E-03 2.420E-03

PER 004EU 006 6.570E-04 2.260E-04 2.260E-04

PER 004EU 043 6.570E-04 2.070E-03 2.070E-03

PER 004GP 010 7.060E-08 3.090E-07 3.090E-07

Totals 8.766E-03 8.766E-03 0.000E+00

Carbon tetrachloride

PER 004GP 007 5.710E-04 1.430E-04 1.430E-04

Totals 1.430E-04 1.430E-04 0.000E+00

Carbon Dioxide Equivalent

PER 004EU 003 2.025E+04 8.868E+04 8.868E+04

PER 004EU 004 3.004E+04 1.316E+05 1.316E+05

PER 004EU 005 3.004E+04 1.316E+05 1.316E+05

PER 004EU 006 3.576E+04 1.121E+05 1.121E+05

PER 004EU 043 3.576E+04 1.127E+05 1.127E+05

PER 004EU 051 6.910E+02 1.730E+02 1.730E+02

PER 004EU 054 6.910E+02 1.730E+02 1.730E+02

PER 004EU 055 1.151E+03 2.880E+02 2.880E+02

PER 004GP 007 1.100E+03 2.750E+02 2.750E+02

PER 004GP 008 2.924E+03 7.310E+02 7.310E+02

PER 004GP 009 1.180E+04 2.949E+03 2.949E+03

PER 004GP 010 7.010E+02 3.071E+03 3.071E+03

Totals 5.842E+05 5.842E+05 0.000E+00

Chlorobenzene

PER 004GP 007 4.180E-04 1.040E-04 1.040E-04

Totals 0.000E+00 0.000E+00 0.000E+00

Chloroform

PER 004GP 007 4.430E-04 1.110E-04 1.110E-04

Totals 1.110E-04 1.110E-04 0.000E+00

Cadmium compounds

PER 004EU 003 3.720E-04 1.630E-03 1.630E-03

PER 004EU 004 5.520E-04 2.420E-03 2.420E-03

PER 004EU 005 5.520E-04 2.420E-03 2.420E-03

PER 004EU 006 6.570E-04 2.260E-04 2.260E-04

PER 004EU 043 6.570E-04 2.070E-03 2.070E-03

Page 2 of 17

19 September, 2014 07:31



RetiredBy

(Action)

AddedBy

(Action)


(tons per yr)

LimitedPotential

(tons per yr)


(tons per yr)

HourlyPotential

(lbs per hr)




Cadmium compounds

PER 004GP 010 6.470E-06 2.830E-05 2.830E-05

Totals 8.794E-03 8.794E-03 0.000E+00

Methane

PER 004EU 003 8.200E-01 3.580E+00 3.580E+00

PER 004EU 004 1.210E+00 5.320E+00 5.320E+00

PER 004EU 005 1.210E+00 5.320E+00 5.320E+00

PER 004EU 006 1.450E+00 2.110E+00 2.110E+00

PER 004EU 043 1.450E+00 4.550E+00 4.550E+00

PER 004EU 051 2.790E-02 1.000E-02 1.000E-02

PER 004EU 054 2.790E-02 1.000E-02 1.000E-02

PER 004EU 055 4.650E-02 1.000E-02 1.000E-02

PER 004GP 007 2.000E-02 5.200E-03 5.200E-03

PER 004GP 008 1.200E-01 3.000E-02 3.000E-02

PER 004GP 009 4.800E-01 1.200E-01 1.200E-01

PER 004GP 010 1.000E-02 6.000E-02 6.000E-02

Totals 2.113E+01 2.113E+01 0.000E+00

Carbon Monoxide

PER 001EU 001 3.790E+00 1.660E+01 1.660E+01 1.300E-01

PER 004EU 001 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 001EU 002 6.420E+00 2.810E+01 2.810E+01 3.960E+00

PER 004EU 002 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 001EU 003 1.021E+01 4.470E+01 4.470E+01 1.498E+01

PER 001EU 004 1.515E+01 6.640E+01 6.640E+01 2.891E+01

PER 004EU 004 1.515E+01 6.640E+01 6.640E+01 0.000E+00

PER 001EU 005 1.515E+01 6.640E+01 6.640E+01 3.375E+01

PER 004EU 005 1.515E+01 6.637E+01 6.637E+01 0.000E+00

PER 001EU 006 1.804E+01 7.900E+01 4.160E+01 1.170E+01

PER 004EU 006 1.804E+01 7.899E+01 7.899E+01 0.000E+00

PER 001EU 042 1.053E+01 4.610E+01 4.530E+01

PER 004EU 042 0.000E+00 0.000E+00 0.000E+00

PER 002EU 043 1.750E+01 7.670E+01 5.500E+01

PER 004EU 043 1.804E+01 7.899E+01 7.899E+01

PER 003EU 044 1.600E-01 7.010E-01 7.010E-01

PER 004EU 044 0.000E+00 0.000E+00 0.000E+00

PER 003EU 045 1.600E-01 7.010E-01 7.010E-01

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(lbs per hr)




Carbon Monoxide

PER 004EU 045 0.000E+00 0.000E+00 0.000E+00

PER 003EU 046 1.600E-01 7.010E-01 7.010E-01

PER 004EU 046 0.000E+00 0.000E+00 0.000E+00

PER 004EU 051 3.470E+00 8.700E-01 8.700E-01

PER 004EU 054 3.470E+00 8.700E-01 8.700E-01

PER 004EU 055 5.800E-01 1.450E+00 1.400E-01

PER 001GP 001 3.580E+00 8.900E-01 8.900E-01 3.000E-02

PER 004GP 001 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 003GP 002 8.694E+01 2.412E+01 2.412E+01 5.200E-01

PER 004GP 002 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 004GP 007 3.630E+00 9.100E-01 9.100E-01

PER 004GP 008 1.701E+01 4.250E+00 4.250E+00

PER 004GP 009 6.141E+01 1.535E+01 1.535E+01

PER 004GP 010 4.900E-01 2.160E+00 2.160E+00

Totals 3.613E+02 3.600E+02 1.498E+01

Carbon Dioxide

PER 004EU 003 2.018E+04 8.837E+04 8.837E+04

PER 004EU 004 2.994E+04 1.311E+05 1.311E+05

PER 004EU 005 2.994E+04 1.311E+05 1.311E+05

PER 004EU 006 3.563E+04 1.120E+05 1.120E+05

PER 004EU 043 3.563E+04 1.123E+05 1.123E+05

PER 004EU 051 6.880E+02 1.720E+02 1.720E+02

PER 004EU 054 6.880E+02 1.720E+02 1.720E+02

PER 004EU 055 1.147E+03 2.870E+02 2.870E+02

PER 004GP 007 1.099E+03 2.750E+02 2.750E+02

PER 004GP 008 2.914E+03 7.280E+02 7.280E+02

PER 004GP 009 1.176E+04 2.939E+03 2.939E+03

PER 004GP 010 7.000E+02 3.068E+03 3.068E+03

Totals 5.825E+05 5.825E+05 0.000E+00

Cobalt compounds

PER 004EU 003 1.020E-05 4.470E-05 4.470E-05

PER 004EU 004 1.520E-05 6.640E-05 6.640E-05

PER 004EU 005 1.520E-05 6.640E-05 6.640E-05

PER 004EU 006 1.800E-05 7.900E-05 7.900E-05

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Cobalt compounds

PER 004EU 043 1.800E-05 7.900E-05 7.900E-05

Totals 3.355E-04 3.355E-04 0.000E+00

Chromium compounds

PER 004EU 003 3.720E-04 1.630E-03 1.630E-03

PER 004EU 004 5.520E-04 2.420E-03 2.420E-03

PER 004EU 005 5.520E-04 2.420E-03 2.420E-03

PER 004EU 006 6.570E-04 1.320E-03 1.320E-03

PER 004EU 043 6.570E-04 2.070E-03 2.070E-03

PER 004GP 010 8.240E-06 3.610E-05 3.610E-05

Totals 9.896E-03 9.896E-03 0.000E+00

1,4-Dichlorobenzene

PER 004EU 003 1.460E-04 6.390E-04 6.390E-04

PER 004EU 004 2.160E-04 9.480E-04 9.480E-04

PER 004EU 005 2.160E-04 9.480E-04 9.480E-04

PER 004EU 006 2.580E-04 1.130E-03 1.130E-03

PER 004EU 043 2.580E-04 1.130E-03 1.130E-03

PER 004GP 010 7.060E-06 3.090E-05 3.090E-05

Totals 4.826E-03 4.826E-03 0.000E+00

1,3-Dichloropropene

PER 004GP 007 4.120E-04 1.030E-04 1.030E-04

Totals 1.030E-04 1.030E-04 0.000E+00

Ethylbenzene

PER 004EU 003 2.970E-02 1.300E-01 1.300E-01

PER 004EU 004 8.480E-05 3.710E-04 3.710E-04

PER 004EU 005 8.480E-05 3.710E-04 3.710E-04

PER 004EU 006 1.010E-04 3.470E-05 3.470E-05

PER 004EU 043 1.010E-04 3.180E-04 3.180E-04

PER 004GP 007 1.020E-03 2.540E-04 2.540E-04

Totals 1.313E-01 1.313E-01 0.000E+00

Formaldehyde

PER 004EU 004 4.400E-02 1.930E-01 1.930E-01

PER 004EU 005 4.400E-02 1.930E-01 1.930E-01

PER 004EU 006 5.240E-02 7.050E-02 7.050E-02

PER 004EU 043 5.240E-02 1.650E-01 1.650E-01

PER 004GP 007 5.200E-01 1.300E-01 1.300E-01

PER 004GP 008 2.110E-02 5.280E-03 5.280E-03

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Formaldehyde

PER 004GP 009 4.130E-05 1.030E-05 1.030E-05

PER 004GP 010 4.410E-04 1.930E-03 1.930E-03

Totals 7.587E-01 7.587E-01 0.000E+00

Hexane

PER 004EU 003 2.190E-01 9.580E-01 9.580E-01

PER 004EU 004 3.250E-01 1.420E+00 1.420E+00

PER 004EU 005 3.250E-01 1.420E+00 1.420E+00

PER 004EU 006 3.900E-01 1.690E+00 1.690E+00

PER 004EU 043 3.900E-01 1.690E+00 1.690E+00

PER 004GP 007 4.190E-03 1.050E-03 1.050E-03

PER 004GP 010 1.060E-02 4.640E-02 4.640E-02

Totals 7.225E+00 7.225E+00 0.000E+00

Methanol

PER 004GP 007 2.330E-02 5.840E-03 5.840E-03

Totals 5.840E-03 5.840E-03 0.000E+00

Naphthalene

PER 004EU 003 1.020E-03 4.450E-03 4.450E-03

PER 004EU 004 1.510E-03 6.600E-03 6.600E-03

PER 004EU 005 1.510E-03 6.600E-03 6.600E-03

PER 004EU 006 1.790E-03 6.160E-04 6.160E-04

PER 004EU 043 1.790E-03 5.650E-03 5.650E-03

PER 004GP 007 9.060E-04 2.270E-04 2.270E-04

PER 004GP 008 1.520E-03 3.800E-04 3.800E-04

PER 004GP 009 6.810E-05 1.700E-05 1.700E-05

PER 004GP 010 3.590E-06 1.570E-05 1.570E-05

Totals 2.456E-02 2.456E-02 0.000E+00

HAPs - Total

PER 001EU 001 8.520E-02 3.730E-01 3.730E-01 3.030E-03

PER 004EU 001 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 001EU 002 1.450E-01 6.330E-01 6.330E-01 9.570E-02

PER 004EU 002 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 001EU 003 2.300E-01 1.010E+00 1.010E+00 3.640E-01

PER 004EU 003 2.610E-01 1.140E+00 1.140E+00 0.000E+00

PER 001EU 004 3.410E-01 1.490E+00 1.490E+00 6.980E-01

PER 004EU 004 3.870E-01 1.700E+00 1.700E+00 0.000E+00

PER 001EU 005 3.410E-01 1.490E+00 1.490E+00 7.990E-01

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HAPs - Total

PER 004EU 005 3.880E-01 1.700E+00 1.700E+00 0.000E+00

PER 001EU 006 4.060E-01 1.780E+00 9.000E-01 2.630E-01

PER 004EU 006 4.060E-01 1.780E+00 1.780E+00 0.000E+00

PER 001EU 042 1.740E-01 7.630E-01 7.050E-01

PER 004EU 042 0.000E+00 0.000E+00 0.000E+00

PER 002EU 043 5.000E-01 2.200E+00 2.200E+00

PER 004EU 043 4.610E-01 1.930E+00 1.930E+00

PER 001GP 001 7.270E-01 1.820E-01 1.820E-01 7.990E-03

PER 001GP 002 5.930E-01 1.480E-01 1.480E-01 3.540E-03

PER 004GP 007 7.470E-01 1.870E-01 1.870E-01

PER 004GP 008 7.090E-02 1.770E-02 1.770E-02

PER 004GP 009 8.920E-04 2.230E-04 2.230E-04

PER 004GP 010 1.110E-02 4.870E-02 4.870E-02

Totals 8.834E+00 8.834E+00 1.153E-02

Mercury

PER 004EU 003 3.720E-04 1.630E-03 1.630E-03

PER 004EU 004 5.520E-04 2.420E-03 2.420E-03

PER 004EU 005 5.520E-04 2.420E-03 2.420E-03

PER 004EU 006 6.570E-04 2.450E-04 2.450E-04

PER 004EU 043 6.570E-04 2.070E-03 2.070E-03

PER 004GP 010 1.530E-06 6.700E-06 6.700E-06

Totals 8.792E-03 8.792E-03 0.000E+00

Phenol

PER 004GP 007 3.960E-04 9.910E-05 9.910E-05

Totals 0.000E+00 0.000E+00 0.000E+00

Styrene

PER 004GP 007 5.160E-04 1.290E-04 1.290E-04

Totals 0.000E+00 0.000E+00 0.000E+00

1,1,2,2-Tetrachloroethane

PER 004GP 007 6.240E-04 1.560E-04 1.560E-04

Totals 1.560E-04 1.560E-04 0.000E+00

Toluene

PER 004EU 003 5.570E-03 2.440E-02 2.440E-02

PER 004EU 004 8.270E-03 3.620E-02 3.620E-02

PER 004EU 005 8.270E-03 3.620E-02 3.620E-02

PER 004EU 006 9.840E-03 3.380E-03 3.380E-03

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Toluene

PER 004EU 043 9.840E-03 3.100E-02 3.100E-02

PER 004GP 007 9.060E-03 2.270E-03 2.270E-03

PER 004GP 008 7.320E-03 1.830E-03 1.830E-03

PER 004GP 009 1.470E-04 3.680E-05 3.680E-05

PER 004GP 010 2.000E-05 8.760E-05 8.760E-05

Totals 1.354E-01 1.354E-01 0.000E+00

1,1,2-Trichloroethane

PER 004GP 007 4.960E-04 1.240E-04 1.240E-04

Totals 0.000E+00 0.000E+00 0.000E+00

Vinyl chloride

PER 004GP 007 2.320E-04 5.810E-05 5.810E-05

Totals 5.810E-05 5.810E-05 0.000E+00

Xylenes (mixed isomers)

PER 004EU 003 9.790E-05 4.290E-04 4.290E-04

PER 004EU 004 8.270E-03 3.620E-02 3.620E-02

PER 004EU 005 1.450E-04 6.370E-04 6.370E-04

PER 004EU 006 1.730E-04 5.940E-05 5.940E-05

PER 004EU 043 1.730E-04 5.450E-04 5.450E-04

PER 004GP 007 2.520E-03 6.310E-04 6.310E-04

PER 004GP 008 5.100E-03 1.280E-03 1.280E-03

PER 004GP 009 1.010E-04 2.530E-05 2.530E-05

Totals 3.981E-02 3.981E-02 0.000E+00

2,2,4-trimethylpentane

PER 004GP 007 7.960E-03 1.990E-03 1.990E-03

Totals 0.000E+00 0.000E+00 0.000E+00

2-Methylnaphthalene

PER 004GP 007 2.010E-04 5.040E-05 5.040E-05

Totals 5.040E-05 5.040E-05 0.000E+00

Manganese compounds

PER 004EU 003 7.440E-04 3.260E-03 3.260E-03

PER 004EU 004 1.100E-03 4.840E-03 4.840E-03

PER 004EU 005 1.100E-03 4.840E-03 4.840E-03

PER 004EU 006 1.310E-03 4.510E-04 4.510E-04

PER 004EU 043 1.310E-03 4.140E-03 4.140E-03

PER 004GP 010 2.240E-06 9.790E-06 9.790E-06

Totals 1.754E-02 1.754E-02 0.000E+00

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Acenaphthene

PER 004GP 007 2.980E-05 7.460E-06 7.460E-06

Totals 0.000E+00 0.000E+00 0.000E+00

Acenaphthylene

PER 004GP 007 2.980E-05 7.460E-06 7.460E-06

Totals 0.000E+00 0.000E+00 0.000E+00

Anthracene

PER 004GP 007 6.760E-06 1.690E-06 1.690E-06

Totals 0.000E+00 0.000E+00 0.000E+00

Benz(a)anthracene

PER 004GP 007 3.160E-06 7.910E-07 7.910E-07

Totals 0.000E+00 0.000E+00 0.000E+00

Benzo(a)pyrene

PER 004GP 007 5.350E-08 1.340E-08 1.340E-08

Totals 0.000E+00 0.000E+00 0.000E+00

Benzo(b)fluoranthene

PER 004GP 007 8.010E-08 2.000E-08 2.000E-08

Totals 0.000E+00 0.000E+00 0.000E+00

Benzo(ghi)perylene

PER 004GP 007 2.330E-07 5.840E-08 5.840E-08

Totals 0.000E+00 0.000E+00 0.000E+00

Benzo(k)fluoranthene

PER 004GP 007 4.010E-08 1.000E-08 1.000E-08

Totals 0.000E+00 0.000E+00 0.000E+00

Chrysene

PER 004GP 007 6.320E-06 1.580E-06 1.580E-06

Totals 0.000E+00 0.000E+00 0.000E+00

Ethylene dibromide (dibromoeth

PER 004GP 007 6.910E-04 1.730E-04 1.730E-04

Totals 0.000E+00 0.000E+00 0.000E+00

Fluoranthene

PER 004GP 007 3.400E-06 8.490E-07 8.490E-07

Totals 0.000E+00 0.000E+00 0.000E+00

Fluorene

PER 004GP 007 1.590E-05 3.980E-06 3.980E-06

Totals 3.980E-06 3.980E-06 0.000E+00

Nitrous Oxide

PER 004EU 003 1.600E-01 7.200E-01 7.200E-01

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Nitrous Oxide

PER 004EU 004 2.400E-01 1.060E+00 1.060E+00

PER 004EU 005 2.400E-01 1.060E+00 1.060E+00

PER 004EU 006 2.900E-01 2.100E-01 2.100E-01

PER 004EU 043 2.900E-01 9.100E-01 9.100E-01

PER 004EU 051 5.580E-03 1.400E-03 1.400E-03

PER 004EU 054 2.790E-02 1.000E-02 1.000E-02

PER 004EU 055 9.310E-03 2.330E-03 2.330E-03

PER 004GP 007 2.070E-03 5.200E-04 5.200E-04

PER 004GP 008 2.000E-02 1.000E-02 1.000E-02

PER 004GP 009 1.000E-01 2.000E-02 2.000E-02

PER 004GP 010 1.320E-03 1.000E-02 1.000E-02

Totals 4.014E+00 4.014E+00 0.000E+00

Indeno(1,2,3-cd)pyrene

PER 004GP 007 9.350E-08 2.340E-08 2.340E-08

Totals 0.000E+00 0.000E+00 0.000E+00

Methylene chloride (dichlorome

PER 004GP 007 1.380E-03 3.460E-04 3.460E-04

Totals 0.000E+00 0.000E+00 0.000E+00

Phenanthrene

PER 004GP 007 3.320E-05 8.310E-06 8.310E-06

Totals 0.000E+00 0.000E+00 0.000E+00

Pyrene

PER 004GP 007 5.500E-06 1.370E-06 1.370E-06

Totals 1.370E-06 1.370E-06 0.000E+00

Nickel compounds

PER 004EU 003 3.720E-04 1.630E-03 1.630E-03

PER 004EU 004 5.520E-04 2.420E-03 2.420E-03

PER 004EU 005 5.520E-04 2.420E-03 2.420E-03

PER 004EU 006 6.570E-04 1.970E-03 1.970E-03

PER 004EU 043 6.570E-04 2.070E-03 2.070E-03

PER 004GP 010 1.240E-05 5.410E-03 5.410E-05

Totals 1.592E-02 1.056E-02 0.000E+00

Nitrogen Oxides

PER 001EU 001 1.687E+01 7.390E+01 7.390E+01 1.290E+00

PER 004EU 001 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 001EU 002 2.860E+01 1.253E+02 1.253E+02 1.380E+01

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Nitrogen Oxides

PER 004EU 002 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 001EU 003 3.885E+01 1.702E+02 1.702E+02 7.003E+01

PER 004EU 003 3.404E+01 1.491E+02 1.491E+02 0.000E+00

PER 001EU 004 5.765E+01 2.525E+02 2.525E+02 1.331E+02

PER 004EU 004 5.051E+01 2.210E+02 2.212E+02 0.000E+00

PER 001EU 005 5.765E+01 2.525E+02 2.525E+02 1.397E+02

PER 004EU 005 5.051E+01 2.212E+02 2.212E+02 0.000E+00

PER 001EU 006 2.409E+01 1.787E+02 4.000E+01 3.930E+00

PER 004EU 006 4.079E+01 1.787E+02 1.787E+02 0.000E+00

PER 001EU 042 1.842E+01 8.070E+01 2.590E+01

PER 004EU 042 0.000E+00 0.000E+00 0.000E+00

PER 002EU 043 2.090E+01 9.140E+01 3.900E+01

PER 004EU 043 4.079E+01 1.787E+02 3.900E+01

PER 003EU 044 1.900E-01 8.340E-01 8.340E-01

PER 004EU 044 2.000E-01 8.600E-01 8.600E-01

PER 003EU 045 1.900E-01 8.340E-01 8.340E-01

PER 004EU 045 2.000E-01 8.600E-01 8.600E-01

PER 003EU 046 1.900E-01 8.340E-01 8.340E-01

PER 004EU 046 2.000E-01 8.600E-01 8.600E-01

PER 004EU 051 3.970E+00 9.900E-01 9.900E-01

PER 004EU 054 6.350E+00 1.590E+00 1.590E+00

PER 004EU 055 1.058E+01 2.650E+00 2.650E+00

PER 001GP 001 2.550E+01 6.400E+00 6.400E+00 2.800E-01

PER 004GP 001 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 003GP 002 4.020E+02 1.033E+02 1.033E+02 2.380E+00

PER 004GP 002 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 004GP 007 2.983E+01 7.460E+00 7.460E+00

PER 004GP 008 7.897E+01 1.974E+01 1.974E+01

PER 004GP 009 2.312E+02 5.780E+01 5.780E+01

PER 004GP 010 5.900E-01 2.580E+00 2.580E+00

Totals 1.044E+03 9.046E+02 0.000E+00

PM < 2.5 micron

PER 004EU 003 1.390E+00 6.100E+00 6.100E+00

PER 004EU 004 2.070E+00 9.050E+00 9.050E+00

PER 004EU 005 2.070E+00 9.050E+00 9.050E+00

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PM < 2.5 micron

PER 004EU 006 2.460E+00 7.150E+00 7.150E+00

PER 004EU 043 2.460E+00 7.750E+00 7.750E+00

PER 004EU 051 2.000E-01 5.000E-02 5.000E-02

PER 004EU 054 2.000E-01 5.000E-02 5.000E-02

PER 004EU 055 5.000E-02 8.000E-02 1.000E-02

PER 004GP 007 4.500E-01 1.100E-01 1.100E-01

PER 004GP 008 5.550E+00 1.390E+00 1.390E+00

PER 004GP 009 4.020E+00 1.000E+00 1.000E+00

PER 004GP 010 4.000E-02 2.000E-01 2.000E-01

Totals 4.198E+01 4.191E+01 0.000E+00

Lead

PER 001EU 001 4.600E-04 2.000E-03 2.000E-03 0.000E+00

PER 004EU 001 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 001EU 002 7.800E-04 3.400E-03 3.400E-03 0.000E+00

PER 004EU 002 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 001EU 003 1.240E-03 5.430E-03 5.430E-03 0.000E+00

PER 004EU 003 6.000E-05 3.000E-04 3.000E-04 0.000E+00

PER 001EU 004 1.840E-03 8.100E-03 8.100E-03 0.000E+00

PER 004EU 004 9.000E-05 4.000E-04 4.000E-04 0.000E+00

PER 001EU 005 1.840E-03 8.100E-03 8.100E-03 0.000E+00

PER 004EU 005 9.000E-05 4.000E-04 4.000E-04 0.000E+00

PER 001EU 006 1.960E-03 8.600E-03 9.100E-04 0.000E+00

PER 004EU 006 1.100E-04 5.000E-04 5.000E-04 0.000E+00

PER 001EU 042 8.390E-04 3.700E-03 5.200E-04

PER 004EU 042 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 004EU 043 1.100E-04 5.000E-04 5.000E-04

PER 001GP 001 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 001GP 002 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 004GP 010 2.940E-06 1.000E-05 1.000E-05

Totals 2.110E-03 2.110E-03 0.000E+00

PM < 10 micron

PER 001EU 001 4.510E+00 1.970E+01 1.970E+01 3.400E-01

PER 004EU 001 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 001EU 002 7.640E+00 3.350E+01 3.350E+01 3.000E+00

PER 004EU 002 0.000E+00 0.000E+00 0.000E+00 0.000E+00

Page 12 of 17

19 September, 2014 07:31



RetiredBy

(Action)

AddedBy

(Action)


(tons per yr)

LimitedPotential

(tons per yr)


(tons per yr)

HourlyPotential

(lbs per hr)




PM < 10 micron

PER 001EU 003 1.339E+01 5.870E+01 5.870E+01 1.179E+01

PER 004EU 003 2.070E+00 9.050E+00 9.050E+00 0.000E+00

PER 001EU 004 1.987E+01 8.700E+01 8.700E+01 2.170E+01

PER 004EU 004 3.070E+00 1.343E+01 1.343E+01 0.000E+00

PER 001EU 005 1.987E+01 8.700E+01 8.700E+01 1.716E+01

PER 004EU 005 3.070E+00 1.343E+01 1.343E+01 0.000E+00

PER 001EU 006 4.600E+00 2.010E+01 1.150E+01 1.070E+00

PER 004EU 006 3.650E+00 7.150E+00 7.150E+00 0.000E+00

PER 001EU 042 6.580E+00 2.880E+01 6.300E+00

PER 004EU 042 0.000E+00 0.000E+00 0.000E+00

PER 002EU 043 3.600E+00 1.580E+01 1.300E+01

PER 004EU 043 3.650E+00 1.150E+01 1.150E+01

PER 003EU 044 1.400E-02 1.400E-02 6.300E-02

PER 004EU 044 0.000E+00 0.000E+00 0.000E+00

PER 003EU 045 1.400E-02 1.400E-02 6.300E-02

PER 004EU 045 0.000E+00 0.000E+00 0.000E+00

PER 003EU 046 1.400E-02 1.400E-02 6.300E-02

PER 004EU 046 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 004EU 051 2.000E-01 5.000E-02 5.000E-02

PER 004EU 054 2.000E-01 5.000E-02 5.000E-02

PER 004EU 055 5.000E-02 8.000E-02 1.000E-02

PER 001GP 001 8.970E-03 2.200E-02 2.200E-02 0.000E+00

PER 004GP 001 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 003GP 002 2.829E+01 7.290E+00 7.290E+00 1.800E-01

PER 004GP 002 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 004GP 007 4.500E-01 1.100E-01 1.100E-01

PER 004GP 008 5.550E+00 1.390E+00 1.390E+00

PER 004GP 009 4.140E+00 1.040E+00 1.040E+00

PER 004GP 010 4.000E-02 2.000E-01 2.000E-01

Totals 5.748E+01 5.741E+01 0.000E+00

Polycyclic organic matter

PER 004EU 003 1.280E-03 5.610E-03 5.610E-03

PER 004EU 004 1.900E-03 8.330E-03 8.330E-03

PER 004EU 005 1.900E-03 8.330E-03 8.330E-03

PER 004EU 006 2.260E-03 7.770E-04 7.770E-04

Page 13 of 17

19 September, 2014 07:31



RetiredBy

(Action)

AddedBy

(Action)


(tons per yr)

LimitedPotential

(tons per yr)


(tons per yr)

HourlyPotential

(lbs per hr)




Polycyclic organic matter

PER 004EU 043 2.260E-03 7.130E-03 7.130E-03

PER 004GP 010 4.100E-06 1.800E-05 1.800E-05

Totals 3.020E-02 3.020E-02 0.000E+00

Total Particulate Matter

PER 001EU 001 5.240E+00 2.300E+01 2.300E+01 4.000E-01

PER 004EU 001 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 001EU 002 8.890E+00 3.890E+01 3.890E+01 3.440E+00

PER 004EU 002 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 001EU 003 1.529E+01 6.700E+01 6.700E+01 1.332E+01

PER 004EU 003 2.970E+00 1.299E+01 1.299E+01 0.000E+00

PER 001EU 004 2.269E+01 9.940E+01 9.940E+01 2.450E+01

PER 004EU 004 4.400E+00 1.927E+01 1.927E+01 0.000E+00

PER 001EU 005 2.269E+01 9.940E+01 9.940E+01 1.923E+01

PER 004EU 005 4.400E+00 1.927E+01 1.927E+01 0.000E+00

PER 001EU 006 4.600E+00 2.010E+01 1.150E+01 1.070E+00

PER 004EU 006 5.240E+00 7.150E+00 7.150E+00 0.000E+00

PER 001EU 042 6.580E+00 2.880E+01 6.300E+00

PER 004EU 042 0.000E+00 0.000E+00 0.000E+00

PER 002EU 043 5.160E+00 2.260E+01 1.800E+01

PER 004EU 043 5.240E+00 1.650E+01 1.650E+01

PER 003EU 044 1.400E-02 6.300E-02 6.300E-02

PER 004EU 044 0.000E+00 0.000E+00 0.000E+00

PER 003EU 045 1.400E-02 6.300E-02 6.300E-02

PER 004EU 045 0.000E+00 0.000E+00 0.000E+00

PER 003EU 046 1.400E-02 6.300E-02 6.300E-02

PER 004EU 046 0.000E+00 0.000E+00 0.000E+00

PER 004EU 051 2.000E-01 5.000E-02 5.000E-02

PER 004EU 054 2.000E-01 5.000E-02 5.000E-02

PER 004EU 055 5.000E-02 8.000E-02 1.000E-02

PER 001GP 001 8.970E-03 2.200E-02 2.200E-02 0.000E+00

PER 004GP 001 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 003GP 002 2.929E+01 7.290E+00 7.290E+00 1.800E-01

PER 004GP 002 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 004GP 007 4.500E-01 1.100E-01 1.100E-01

PER 004GP 008 5.550E+00 1.390E+00 1.390E+00

Page 14 of 17

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RetiredBy

(Action)

AddedBy

(Action)


(tons per yr)

LimitedPotential

(tons per yr)


(tons per yr)

HourlyPotential

(lbs per hr)




Total Particulate Matter

PER 004GP 009 5.040E+00 1.260E+00 1.260E+00

PER 004GP 010 4.000E-02 2.000E-01 2.000E-01

Totals 7.832E+01 7.825E+01 0.000E+00

Selenium compounds

PER 004EU 003 1.860E-03 8.150E-03 8.150E-03

PER 004EU 004 2.760E-03 1.210E-02 1.210E-02

PER 004EU 005 2.760E-03 1.210E-02 1.210E-02

PER 004EU 006 3.290E-03 1.130E-03 1.130E-03

PER 004EU 043 3.290E-03 1.040E-02 1.040E-02

PER 004GP 010 1.410E-07 6.180E-07 6.180E-07

Totals 4.388E-02 4.388E-02 0.000E+00

HAP-Single

PER 002EU 043 3.700E-01 1.640E+00 1.600E+00

Totals 1.640E+00 1.600E+00 0.000E+00

Sulfur Dioxide

PER 001EU 001 7.222E+01 3.163E+02 3.163E+02 5.460E+00

PER 004EU 001 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 001EU 002 1.225E+02 5.364E+02 5.364E+02 4.364E+01

PER 004EU 002 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 001EU 003 1.947E+02 8.527E+02 8.527E+02 1.561E+02

PER 004EU 003 6.380E+00 2.794E+01 2.794E+01 0.000E+00

PER 001EU 004 2.889E+02 1.265E+03 1.265E+03 2.857E+02

PER 004EU 004 9.470E+00 4.146E+01 4.146E+01 0.000E+00

PER 001EU 005 2.889E+02 1.265E+03 1.265E+03 2.112E+02

PER 004EU 005 9.470E+00 4.146E+01 4.146E+01 0.000E+00

PER 001EU 006 1.111E+02 4.865E+02 3.900E+01 3.700E-01

PER 004EU 006 1.127E+01 3.870E+00 3.870E+00 0.000E+00

PER 001EU 042 4.767E+01 2.088E+02 2.080E+01

PER 004EU 042 0.000E+00 0.000E+00 0.000E+00

PER 002EU 043 1.160E+01 5.060E+01 3.350E+01

PER 004EU 043 1.127E+01 3.550E+01 3.550E+01

PER 003EU 044 1.000E-03 5.000E-03 5.000E-03

PER 004EU 044 1.000E-03 1.000E-02 1.000E-02

PER 003EU 045 1.000E-03 5.000E-03 5.000E-03

PER 004EU 045 1.000E-03 1.000E-02 1.000E-02

Page 15 of 17

19 September, 2014 07:31



RetiredBy

(Action)

AddedBy

(Action)


(tons per yr)

LimitedPotential

(tons per yr)


(tons per yr)

HourlyPotential

(lbs per hr)




Sulfur Dioxide

PER 003EU 046 1.000E-03 5.000E-03 5.000E-03

PER 004EU 046 1.000E-03 1.000E-02 1.000E-02

PER 004EU 051 6.390E-05 1.600E-05 1.600E-05

PER 004EU 054 6.400E-01 1.600E-01 1.600E-01

PER 004EU 055 1.070E+00 2.700E-01 2.700E-02

PER 001GP 001 5.380E-03 1.300E-03 1.300E-03 0.000E+00

PER 004GP 001 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 003GP 002 2.638E+01 6.610E+00 6.610E+00 1.600E-01

PER 004GP 002 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 004GP 007 1.000E-02 1.380E-03 1.380E-03

PER 004GP 008 5.190E+00 1.300E+00 1.300E+00

PER 004GP 009 3.649E+01 9.120E+00 9.120E+00

PER 004GP 010 3.530E-03 2.000E-02 2.000E-02

Totals 1.611E+02 1.609E+02 0.000E+00

Volatile Organic Compounds

PER 001EU 001 2.500E-01 1.100E+00 1.100E+00 1.000E-02

PER 004EU 001 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 001EU 002 4.200E-01 1.800E+00 1.800E+00 2.500E-01

PER 004EU 002 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 001EU 003 6.700E-01 2.900E+00 2.900E+00 9.500E-01

PER 004EU 003 6.700E-01 2.930E+00 2.930E+00 0.000E+00

PER 001EU 004 9.900E-01 4.300E+00 4.300E+00 1.830E+00

PER 004EU 004 9.900E-01 4.350E+00 4.350E+00 0.000E+00

PER 001EU 005 9.900E-01 4.300E+00 4.300E+00 2.170E+00

PER 004EU 005 9.900E-01 4.350E+00 4.350E+00 0.000E+00

PER 001EU 006 1.180E+00 5.200E+00 2.700E+00 7.700E-01

PER 004EU 006 1.180E+00 5.170E+00 5.170E+00 0.000E+00

PER 001EU 042 1.070E+00 4.700E+00 4.500E+00

PER 004EU 042 0.000E+00 0.000E+00 0.000E+00

PER 002EU 043 1.150E+00 5.000E+00 3.000E+00

PER 004EU 043 1.180E+00 5.170E+00 5.170E+00

PER 003EU 044 1.000E-02 4.600E-02 4.600E-02

PER 004EU 044 0.000E+00 0.000E+00 0.000E+00

PER 003EU 045 1.000E-02 4.600E-02 4.600E-02

PER 004EU 045 0.000E+00 0.000E+00 0.000E+00

Page 16 of 17

19 September, 2014 07:31



RetiredBy

(Action)

AddedBy

(Action)


(tons per yr)

LimitedPotential

(tons per yr)


(tons per yr)

HourlyPotential

(lbs per hr)




Volatile Organic Compounds

PER 003EU 046 1.000E-02 4.600E-02 4.600E-02

PER 004EU 046 0.000E+00 0.000E+00 0.000E+00

PER 004EU 051 3.800E-01 9.000E-02 9.000E-02

PER 004EU 054 3.800E-01 1.000E-01 1.000E-01

PER 004EU 055 6.300E-01 1.600E-01 1.600E-01

PER 001GP 001 1.040E+00 2.600E-01 2.600E-01 1.000E-02

PER 004GP 001 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 003GP 002 3.279E+01 8.350E+00 8.350E+00 2.100E-01

PER 004GP 002 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 004GP 007 1.130E+00 2.800E-01 2.800E-01

PER 004GP 008 6.450E+00 1.610E+00 1.610E+00

PER 004GP 009 5.920E+00 1.480E+00 1.480E+00

PER 004GP 010 3.000E-02 1.400E-01 1.400E-01

PER 001TK 001 2.990E-03 1.300E-02 1.300E-02 1.000E-02

PER 004TK 001 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 001TK 002 1.960E-01 8.600E-01 8.600E-01 4.300E-01

PER 001TK 003 2.930E-01 1.280E+00 1.280E+00 6.400E-01

PER 001TK 004 2.990E-03 1.300E-02 1.300E-02 1.000E-02

PER 004TK 004 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 001TK 005 5.710E-04 3.000E-03 3.000E-03 0.000E+00

PER 004TK 005 0.000E+00 0.000E+00 0.000E+00 0.000E+00

PER 001TK 006 4.110E-05 2.000E-04 2.000E-04 0.000E+00

PER 004TK 006 5.940E-05 2.600E-04 2.600E-04 0.000E+00

PER 004TK 007 6.200E-03 3.000E-02 3.000E-02

Totals 2.800E+01 2.800E+01 1.070E+00

Page 17 of 17

MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01


Permit Number: 12300694 - 004

12 Dec, 2014 09:18Page 1 of 73

Subject Item: Total Facility

NC/CA

Type Citation Requirement

CD hdr SOURCE-SPECIFIC REQUIREMENTS1.0

CD Minn. R. 7007.0800, subp. 2 The Permittee is authorized to install and operate EU055, a compression ignition,1005 Hp, diesel emergency generator, at Building 280, at any time within 5 years ofissuance of Air Emissions Permit No.12300694-004. The unit shall meet all therequirements of this permit.

2.0

CD Minn. R. 7007.0800, subp. 2 Permit Appendices: This permit contains appendices as listed in the permit Table ofContents. The Permittee shall comply with all requirements contained in AppendixII: Insignificant Activities and Applicable Requirements.

Modeling parameters in Appendix I: Stack Parameters Relied Upon to DemonstrateCompliance with the NAAQS for PM10 are included for reference only as describedelsewhere in Table A.

3.0

CD Minn. R. 4410.4300; Minn. R.4410.4400

The Permittee shall not begin construction of any single project or projects that areconnected or phased which will cause a total increase in actual emissions ofgreater than 249 tons per year for any criteria pollutant without first getting a permitamendment to authorize the project. Connected and phased have meanings asdefined in Minn. R. 4410.0200, subps. 9b and 60. The Permittee shall not beginconstruction of any other project which is listed in Minn. R. 4410.4300 or Minn. R.4410.4400 without first getting a permit amendment to authorize the project. Suchprojects may require the completion of an Environmental Assessment Worksheet oran Environmental Impact Statement prior to the amendment being issued. This is astate only requirement and is not federally enforceable.

4.0

CD 40 CFR pt. 82 The facility currently uses ozone-depleting substances as defined in 40 CFR pt. 82.Sections 601-618 of the 1990 Clean Air Act Amendments and 40 CFR pt. 82 mayapply to your facility. Read Sections 601-618 and 40 CFR pt. 82 to determine allthe requirements that apply to your facility.

5.0

CD Minn. R. 7007.0800, subps. 2, 4and 5

Recordkeeping for emergency engines: The Permittee shall keep and maintainonsite a list of all emergency engines that are subject to 40 CFR pt. 60, subps. IIIIor JJJJ, or 40 CFR pt. 63, subp. ZZZZ. The list shall clearly identify the engineEU#; which building the engine is located in, on or nearby; engine order date;engine commence construction date; engine installation date; engine model year;engine size in Hp and kW; engine type: compression ignition or spark ignition; andthe date a permit amendment application was submitted to the MPCA.

6.0

CD Hdr PM 2.5 MONITORING REQUIREMENTS7.0

CD 40 CFR pt. 50; 40 CFR pt. 58;Minn. Stat. Sec. 116.07, subds. 4aand 9; Minn. R. 7007.0100, subps.7A, 7L and 7M; Minn. R.7007.0800, subps. 1, 2, and 4;Minn. R. 7009.0010-7009.0080

Ambient Air Monitoring for PM2.5: The Permittee shall demonstrate compliancewith the PM2.5, as defined at Minn. R. 7005.0100, 24-hour and annual NAAQSstandards by conducting PM2.5 monitoring as specified in the Air Monitoring Plan.

8.0


Monitoring Plan: due 180 days after Permit Issuance. Appendix III: Exhibit M:Ambient Air Monitoring Procedures for Determination of Compliance contains theminimum requirements that shall be included in the Monitoring Plan.

The Monitoring Plan shall meet the requirements of 40 CFR pt. 58.

The Quality Assurance provisions in the Monitoring plan shall meet therequirements of 40 CFR pt. 58, Appendix A.

The Permittee shall comply with the methods in 40 CFR pt. 50, Appendix L fordetermining the ambient PM2.5 concentration.

The Permittee shall submit a Monitoring Plan to the Commissioner for approval.MPCA approval of the Monitoring Plan is required before implementation of theMonitoring Plan.

9.0


Revisions to the Monitoring plan: due 60 days after receipt of written MPCA requestfor revisions to the submitted Monitoring Plan.

10.0




12 Dec, 2014 09:18Page 2 of 73


Revisions to the MPCA approved Monitoring plan. The Permittee shall submitproposed changes to the MPCA Approved Monitoring plan to the Commissionerand shall wait for written approval before making such changes.

11.0

CD Minn. R. 7007.0800, subps. 4 and5

The Permittee shall operate a meteorological station for the duration of the ambientair monitoring for PM2.5. The meteorological station shall collect, at a minimum,temperature, wind speed, wind direction. The data collection frequency for theseparameters shall be included in the MPCA approved Monitoring Plan.

12.0

S/A 40 CFR pt. 50; 40 CFR pt. 58;Minn. Stat. Sec. 116.07, subds. 4aand 9; Minn. R. 7007.0100, subps.7A, 7L and 7M; Minn. R.7007.0800, subps. 1, 2, and 4;Minn. R. 7009.0010-7009.0080

Monitoring Plan: due 60 days after end of each calendar year following receipt ofwritten MPCA approval of the previous monitoring plan. The plan shall be updatedannually by the Permittee. The Permittee shall implement the updated MonitoringPlan after receiving approval from the Commissioner.

13.0

S/A 40 CFR pt. 50; 40 CFR pt. 58;Minn. Stat. Sec. 116.07, subds. 4aand 9; Minn. R. 7007.0100, subps.7A, 7L and 7M; Minn. R.7007.0800, subps. 1, 2, and 4;Minn. R. 7009.0010-7009.0080

The Permittee shall install and begin to monitor ambient PM2.5 concentrationaccording to the MPCA approved Monitoring Plan. Monitor Install: due 365 daysafter receipt of written MPCA approval

14.0

S/A Minn. R. 7007.0800, subp. 6 Notification: due 15 days after Initial Startup of the Monitor for PM2.5 as describedin the Monitoring Plan.

15.0


The Permittee shall compile PM2.5 monitoring results by the last day of eachmonth for the previous month. The results shall be made available for inspectionupon request.

16.0

S/A Minn. R. 7007.0800, subps. 5 and6

Ambient Air Monitoring Report: due 45 days after end of each calendar quarterfollowing Initial Startup of the Monitor for PM2.5 in accordance with the MonitoringPlan. The PM2.5 monitoring results shall be submitted to the Commissioner 45days after end of each calendar quarter following startup of the PM2.5 monitor.

17.0

CD Minn. R. 7007.0800, subp. 4 Recordkeeping of Operations for Permit Listed Emission Units that emit PM2.5:The Permittee shall record the hours of operation for emission units that emitPM2.5 based on the monitoring plan. Recordkeeping shall include the date, thenumber of hours operated, and the emission unit. For pilot plants, therecordkeeping will be documented at the pilot plant level (i.e., not required forindividual pieces of equipment within each pilot plant). The Permittee is notrequired to include the following units covered under Permit No. 12300015-0010,as amended, as part of this recordkeeping requirement: miscellaneous laboratorysources (EU008), machine shops (EU009) and carpentry shops (EU010).

18.0

CD Hdr MODELING REQUIREMENTS19.0

CD Minn. Stat. Section 116.07, subds.4a & 9; Minn. R. 7007.0100, subp.7(A), 7(L), & 7(M); Minn. R.7007.0800, subps. 1, 2 & 4; Minn.R. 7009.0010-7009.0080

Modeled Parameters for PM10: The parameters used in PM10 modeling for permitnumber 12300694-004 are listed in Appendix I of this permit. The parametersdescribe the operation of the facility at maximum permitted capacity. The purposeof listing the parameters in the appendix is to provide a benchmark for futurechanges.

20.0


Equivalent or Better Dispersion (EBD) Modeling Triggers for PM10: Changes thatrequire a moderate or major permit amendment and affect any modeled parameteror emission rate listed in Appendix I, or an addition to the information documentedin Appendix I, trigger the EBD Remodeling Submittal requirement. The Permitteeshall include previously made changes to modeled parameters and emission rateslisted in Appendix I that did not previously trigger the EBD Modeling Submittalrequirement with this modeling submittal.

21.0


Equivalent or Better Dispersion (EBD) Modeling Triggers (Modeling Not Required)for PM10: Changes that do not require a permit amendment or that require a minoror administrative permit amendment, and that affect any modeled parameter oremission rate documented in Appendix I, or an addition to the informationdocumented in Appendix I, do not trigger the EBD Modeling Submittal requirement.The Permittee shall keep updated records on site of all modeled parameters andemission rates listed in Appendix I. The Permittee shall submit any changes tomodeled parameters and emission rates with the next required modeling submittal.

22.0




12 Dec, 2014 09:18Page 3 of 73


EBD Modeling Submittal for PM10: For changes meeting the criteria in the EBDModeling Triggers (Modeling Required) requirement, the Permittee shall submit anEBD modeling submittal in accordance with the current version of the MPCA AirDispersion Modeling Guidance and shall wait for written approval (for majoramendments, in the form of an issued permit amendment; for moderateamendments, in the form of a construction authorization letter) before making suchchanges.

23.0


EBD Modeling Submittal Content for PM10: The information submitted mustinclude, for stack and vent sources, source emission rate, location, height,diameters, exit velocity, exit temperature, discharge direction, use of rain caps orrain hats, and, if applicable, locations and dimensions of nearby buildings. Fornon-stack/vent sources, this includes the source emission rate, location, size andshape, release height, and, if applicable, any emission rate scalars, and the initiallateral dimensions and initial vertical dimensions and adjacent building heights.

24.0


Outdated EBD Baseline Modeling for PM10: Prior to conducting the EBD analysis,the Permittee shall use the current version of the MPCA Air Dispersion ModelingGuidance to determine if the Baseline Modeling (the most recent refined modelingdemonstration) is outdated. If the Baseline Modeling is outdated, the Permitteeshall update the Baseline Modeling to be consistent with the current version of theMPCA Air Dispersion Modeling Guidance. The updated modeling will become thenew Baseline Modeling.

This requirement does not require the Permittee to complete a new refinedmodeling demonstration using the revisions made for the EBD demonstration.

25.0


EBD Modeling Results for PM10: The dispersion characteristics due to therevisions of the information in Appendix I must be equivalent to or better than thedispersion characteristics modeled 12/28/2011. The Permittee shall demonstratethis equivalency in the proposal.

26.0


Computer Dispersion Modeling Triggers for PM10: The Permittee shall conduct arefined remodeling analysis in accordance with the Computer Dispersion Modelingrequirements of this permit and the current version of the MPCA Air DispersionModeling Guidance if: (1) the results of the EBD modeling analysis do notdemonstrate equivalent or better dispersion characteristics; (2) a conclusion cannotreadily be made about the dispersion, or (3) the criteria in the EBD ModelingTriggers requirement are met and the Permittee has previously conducted threesuccessive EBD analyses using the same Baseline Modeling.

27.0


Computer Dispersion Modeling Protocol: due 180 days after receipt of writtenMPCA request for PM10 refined modeling. The Permittee shall submit a ComputerDispersion Modeling Protocol that is complete and approvable by MPCA by thedeadline in this requirement. This protocol will describe the proposed modelingmethodology and input data, in accordance with the current version of the MPCAAir Dispersion Modeling Guidance.

28.0


Computer Dispersion Modeling Protocol: due 60 days after receipt of written MPCArequest for revisions to the submitted protocol for PM10 modeling.

29.0


Computer Dispersion Modeling Results: due 180 days after receipt of written MPCAapproval of Computer Dispersion Modeling Protocol for PM10. The Permittee shallsubmit a final Computer Dispersion Modeling Report that is complete andapprovable by MPCA by the deadline in this requirement. The submittal shalladhere to the current version of the MPCA Air Dispersion Modeling Guidance andthe approved Computer Dispersion Modeling Protocol.

30.0

CD hdr DETERMINING IF A PROJECT/MODIFICATION IS SUBJECT TO NSR31.0




12 Dec, 2014 09:18Page 4 of 73

CD Title I Condition: 40 CFR Section52.21(r)(6); Minn. R. 7007.3000;Minn. R. 7007.0800, subp. 2

These requirements apply if a reasonable possibility (RP) as defined in 40 CFRSection 52.21(r)(6)(vi) exists that a proposed project, analyzed using theactual-to-projected-actual (ATPA) test (either by itself or as part of the hybrid test atSection 52.21(a)(2)(iv)(f)) and found to not be part of a major modification, mayresult in a significant emissions increase (SEI). If the ATPA test is not used for theproject, or if there is no RP that the proposed project could result in a SEI, theserequirements do not apply to that project. The Permittee is only subject to thePreconstruction Documentation requirement for a project where a RP occurs onlywithin the meaning of Section 52.21(r)(6)(vi)(b).

Even though a particular modification is not subject to New Source Review (NSR),or where there isn't a RP that a proposed project could result in a SEI, a permitamendment, recordkeeping, or notification may still be required by Minn. R.7007.1150 - 7007.1500.

32.0

CD Title I Condition: 40 CFR Section52.21(r)(6); Minn. R. 7007.3000

Preconstruction Documentation -- Before beginning actual construction on aproject, the Permittee shall document the following:

1. Project description2. Identification of any emission unit (EU) whose emissions of an NSR pollutantcould be affected3. A description of the applicability test used to determine that the project is not amajor modification for any regulated NSR pollutant, including the baseline actualemissions, the projected actual emissions, the amount of emissions excluded dueto increases not associated with the modification and that the EU could haveaccommodated during the baseline period, an explanation of why the amountswere excluded, and any creditable contemporaneous increases and decreases thatwere considered in the determination.

The Permittee shall maintain records of this documentation.

33.0

CD Minn. R. 7007.1200, subp. 4;Minn. R. 7007.0800, subps. 4 & 5

Additional Preconstruction Documentation -- Before beginning actual constructionon a project, the Permittee shall document the following:

1. Pre-change potential emissions of any affected existing EU, and the projectedpost-change potential emissions of any affected existing or new EU.

The Permittee shall maintain records of this documentation.

34.0

CD Title I Condition: 40 CFR Section52.21(r)(6); Minn. R. 7007.3000;Minn. R. 7007.0800, subps. 4 & 5

The Permittee shall monitor the actual emissions of any regulated NSR pollutantthat could increase as a result of the project and that were analyzed using theATPA test, and the potential emissions of any regulated NSR pollutant that couldincrease as a result of the project and that were analyzed using potential emissionsin the hybrid test. The Permittee shall calculate and maintain a record of the sum ofthe actual and potential (if the hybrid test was used in the analysis) emissions of theregulated pollutant, in tons per year on a calendar year basis, for a period of 5years following resumption of regular operations after the change, or for a period of10 years following resumption of regular operations after the change if the projectincreases the design capacity of or potential to emit of any unit associated with theproject.

35.0

CD Title I Condition: 40 CFR Section52.21(r)(6); Minn. R. 7007.3000;Minn. R. 7007.0800, subps. 4 & 5

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 preconstructionprojection and exceed the baseline actual emissions by a significant amount aslisted at 40 CFR Section 52.21(b)(23). Such report shall be submitted to theAgency 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 ofthe facility contact personb. The annual emissions (actual, plus potential if any part of the project wasanalyzed using the hybrid test) for each pollutant for which the preconstructionprojection and significant emissions increase are exceeded.c. Any other information, such as an explanation as to why the summed emissionsdiffer from the preconstruction projection.

36.0

CD hdr OPERATIONAL REQUIREMENTS37.0


The Permittee shall comply with National Primary and Secondary Ambient AirQuality Standards, 40 CFR pt. 50, and the Minnesota Ambient Air QualityStandards, Minn. R. 7009.0010 to 7009.0080. Compliance shall be demonstratedupon written request by the MPCA.

38.0




12 Dec, 2014 09:18Page 5 of 73

CD Minn. R. 7011.0020 Circumvention: Do not install or use a device or means that conceals or dilutesemissions, which would otherwise violate a federal or state air pollution control rule,without reducing the total amount of pollutant emitted.

39.0

CD Minn. R. 7007.0800, subp. 2;Minn. R. 7007.0800, subp. 16(J)

Air Pollution Control Equipment: Operate all pollution control equipment wheneverthe corresponding process equipment and emission units are operated.

40.0

CD Minn. R. 7007.0800, subps. 14and 16(J)

Operation and Maintenance Plan: Retain at the stationary source an operation andmaintenance plan for all air pollution control equipment. At a minimum, the O & Mplan shall identify all air pollution control equipment and control practices and shallinclude a preventative maintenance program for the equipment and practices, adescription of (the minimum but not necessarily the only) corrective actions to betaken to restore the equipment and practices to proper operation to meet applicablepermit conditions, a description of the employee training program for properoperation and maintenance of the control equipment and practices, and the recordskept to demonstrate plan implementation.

41.0

CD Minn. R. 7019.1000, subp. 4 Operation Changes: In any shutdown, breakdown, or deviation the Permittee shallimmediately take all practical steps to modify operations to reduce the emission ofany regulated air pollutant. The Commissioner may require feasible and practicalmodifications in the operation to reduce emissions of air pollutants. No emissionsunits that have an unreasonable shutdown or breakdown frequency of process orcontrol equipment shall be permitted to operate.

42.0

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

43.0

CD Minn. R. 7030.0010 - 7030.0080 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 orcitizens under the Clean Air Act.

44.0

CD Minn. R. 7007.0800, subp. 9(A) Inspections: The Permittee shall comply with the inspection procedures andrequirements as found in Minn. R. 7007.0800, subp. 9(A).

45.0

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

46.0

CD hdr PERFORMANCE TESTING47.0

CD Minn. R. ch. 7017 Performance Testing: Conduct all performance tests in accordance with Minn. R.ch. 7017 unless otherwise noted in Tables A, B, and/or C.

48.0

CD Minn. R. 7017.2018; Minn. R.7017.2030, subps. 1-4, Minn. R.7017.2035, subps. 1-2

Performance Test Notifications and Submittals:

Performance Tests are due as outlined in Table A of the permit.See Table B for additional testing requirements.

Performance Test Notification (written): due 30 days before each Performance TestPerformance Test Plan: due 30 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 may be submitted in an alternativeformat as allowed by Minn. R. 7017.2018.

49.0

CD Minn. R. 7017.2025, subp. 3 Limits set as a result of a performance test (conducted before or after permitissuance) apply until superseded as stated in the MPCA's Notice of Complianceletter granting preliminary approval. Preliminary approval is based on formal reviewof 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 amendmentincorporating the change.

50.0

CD hdr MONITORING REQUIREMENTS51.0

CD Minn. R. 7007.0800, subp. 4(D) Monitoring Equipment Calibration - The Permittee shall either:

1. Calibrate or replace required monitoring equipment every 12 months; or2. Calibrate at the frequency stated in the manufacturer's specifications.

For each monitor, the Permittee shall maintain a record of all calibrations, includingthe date conducted, and any corrective action that resulted. The Permittee shallinclude the calibration frequencies, procedures, and manufacturer's specifications(if applicable) in the Operations and Maintenance Plan. Any requirements applyingto continuous emission monitors are listed separately in this permit.

52.0




12 Dec, 2014 09:18Page 6 of 73

CD Minn. R. 7007.0800, subp. 4(D) Operation of Monitoring Equipment: Unless otherwise noted in Tables A, B, and/orC, monitoring a process or control equipment connected to that process is notnecessary during periods when the process is shutdown, or during checks of themonitoring systems, such as calibration checks and zero and span adjustments. Ifmonitoring records are required, they should reflect any such periods of processshutdown or checks of the monitoring system.

53.0

CD hdr RECORDKEEPING54.0

CD Minn. R. 7007.0800, subp. 5(C) Recordkeeping: Retain all records at the stationary source, unless otherwisespecified 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 locationinclude all calibration and maintenance records, all original recordings forcontinuous monitoring instrumentation, and copies of all reports required by thepermit. Records must conform to the requirements listed in Minn. R. 7007.0800,subp. 5(A).

55.0

CD Minn. R. 7007.0800, subp. 5(B) Recordkeeping: Maintain records describing any insignificant modifications (asrequired by Minn. R. 7007.1250, subp. 3) or changes contravening permit terms (asrequired by Minn. R. 7007.1350, subp. 2), including records of the emissionsresulting from those changes.

56.0

CD Minn. R. 7007.1200, subp. 4 If the Permittee determines that no permit amendment or notification is requiredprior to making a change, the Permittee must retain records of all calculationsrequired under Minn. R. 7007.1200. For expiring permits, these records shall bekept for a period of five years from the date the change was made or until permitreissuance, whichever is longer. The records shall be kept at the stationary sourcefor the current calendar year of operation and may be kept at the stationary sourceor office of the stationary source for all other years. The records may be maintainedin either electronic or paper format.

57.0

CD Minn. R. 7007.0800, subp. 2 Equipment Labeling: The Permittee shall permanently affix a unique number toeach emissions unit for tracking purposes. The numbers shall correlate the unit tothe appropriate EU and GP numbers used in this permit. The number can beaffixed by placard, stencil, or other means. The number shall be maintained so thatit is readable and visible at all times from a safe distance. If equipment is added, itshall be given a new unique number; numbers from replaced or removedequipment shall not be reused.

58.0

CD hdr REPORTING/SUBMITTALS59.0

S/A 40 CFR Section 60.7(c); Minn. R.7017.1110, subp. 1 & 2

Excess Emissions/Downtime Reports (EER's): due 30 days after end of eachcalendar quarter following Permit Issuance Submit Deviations Reporting FormDRF-1 as amended. The EER shall indicate all periods of monitor bypass and allperiods of exceedances of a limit including exceedances allowed by an applicablestandard, i.e. during start-up, shutdown, and malfunctions. The EER must besubmitted even if there were no excess emissions, downtime or bypasses duringthe quarter.

This requirement applies to each continuous emissions monitoring system (CEMS)and to each continuous opacity monitoring system (COMS) individually.

60.0

CD Minn. R. 7019.1000, subp. 3 Shutdown Notifications: Notify the Commissioner at least 24 hours in advance of aplanned shutdown of any control equipment or process equipment if the shutdownwould cause any increase in the emissions of any regulated air pollutant. If theowner 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 required in the circumstances outlined in Items A, Band C of Minn. R. 7019.1000, subp. 3.

At the time of notification, the owner or operator shall inform the Commissioner ofthe cause of the shutdown and the estimated duration. The owner or operator shallnotify the Commissioner when the shutdown is over.

61.0




12 Dec, 2014 09:18Page 7 of 73

CD Minn. R. 7019.1000, subp. 2 Breakdown Notifications: Notify the Commissioner within 24 hours of a breakdownof more than one hour duration of any control equipment or process equipment ifthe breakdown causes any increase in the emissions of 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 notrequired 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 operatorshall inform the Commissioner of the cause of the breakdown and the estimatedduration. The owner or operator shall notify the Commissioner when the breakdownis over.

62.0

CD Minn. R. 7019.1000, subp. 1 Notification of Deviations Endangering Human Health or the Environment: As soonas possible after discovery, notify the Commissioner or the state duty officer, eitherorally or by facsimile, of any deviation from permit conditions which could endangerhuman health or the environment.

63.0

CD Minn. R. 7019.1000, subp. 1 Notification of Deviations Endangering Human Health or the Environment Report:Within 2 working days of discovery, notify the Commissioner in writing of anydeviation from permit conditions which could endanger human health or theenvironment. 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 yetcorrected; and5. steps taken or planned to reduce, eliminate, and prevent reoccurrence of thedeviation.

64.0

S/A Minn. R. 7007.0800, subp. 6(A)(2) Semiannual Deviations Report: due 30 days after end of each calendar half-yearfollowing Permit Issuance. The first semiannual report submitted by the Permitteeshall cover the calendar half-year in which the permit is issued. The first report ofeach calendar year covers January 1 - June 30. The second report of eachcalendar year covers July 1 - December 31. If no deviations have occurred, thePermittee shall submit the report stating no deviations.

65.0

CD Minn. R. 7007.1150 - 7007.1500 Application for Permit Amendment: If a permit amendment is needed, submit anapplication in accordance with the requirements of Minn. R. 7007.1150 throughMinn. R. 7007.1500. Submittal dates vary, depending on the type of amendmentneeded.

66.0

S/A Minn. R. 7007.0400, subp. 2 Application for Permit Reissuance: due 180 days before expiration of ExistingPermit

67.0

CD Minn. R. 7007.1400, subp. 1(H) Extension Requests: The Permittee may apply for an Administrative Amendment toextend a deadline in a permit by no more than 120 days, provided the proposeddeadline extension meets the requirements of Minn. R. 7007.1400, subp. 1(H).Performance testing deadlines from the General Provisions of 40 CFR pt. 60 andpt. 63 are examples of deadlines for which the MPCA does not have authority togrant extensions and therefore do not meet the requirements of Minn. R.7007.1400, subp. 1(H).

68.0

S/A Minn. R. 7007.0800, subp. 6(C) Compliance Certification: due 31 days after end of each calendar year followingPermit Issuance (for the previous calendar year). The Permittee shall submit this tothe Commissioner on a form approved by the Commissioner. This report covers alldeviations experienced during the calendar year.

69.0

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

70.0

CD Minn. R. 7002.0005 - 7002.0095 Emission Fees: due 30 days after receipt of an MPCA bill.71.0




12 Dec, 2014 09:18Page 8 of 73

Subject Item: GP 001 Existing, SI, <= 500 Hp, Emergency Engines

Associated Items: EU 008 NG Generator 201 - Reciprocating IC Engine

EU 009 NG Generator 205 - Reciprocating IC Engine





NC/CA


CD Minn. R. 7007.0800, subp. 2 The following requirements apply individually to each item listed in GP001. SeeGP011 for Best Management Practices requirements that also apply.

1.0

CD hdr EMISSION AND OPERATING LIMITS - MINN STANDARDS OF PERFORMANCE2.0

LIMIT Minn. R. 7011.2300, subp. 1 Opacity: less than or equal to 20 percent opacity once operating temperatures havebeen attained.

3.0

LIMIT Minn. R. 7011.2300, subp. 2 Sulfur Dioxide: less than or equal to 0.50 lbs/million Btu heat input .4.0

CD Minn. R. 7005.0100, subp. 35a Fuel type: Natural gas only by design.5.0

CD Minn. R. 7007.0800, subps. 4 & 5 Hours of Operation: Maintain documentation on site for each unit that the unit is anemergency generator by design that qualifies under the U.S. EPA memorandumentitled "Calculating Potential to Emit (PTE) for Emergency Generators" datedSeptember 6, 1995, limiting operation to 500 hours per year.

6.0

CD Hdr NESHAP SUBPART ZZZZ OPERATING REQUIREMENTS7.0

CD 40 CFR Section 63.6602; 40 CFRpt. 63, subp. ZZZZ, Table 2c(6);Minn. R. 7011.8150

Change oil and filter every 500 hours of operation or annually, whichever comesfirst.

The Permittee has the option to utilize an oil analysis program as described later inthis permit in order to extend the specified oil change requirement.

8.0


Inspect spark plugs every 1,000 hours of operation or annually, whichever comesfirst, and replace as necessary.

9.0


Inspect all hoses and belts every 500 hours of operation or annually, whichevercomes first, and replace as necessary.

10.0

CD 40 CFR Section 63.6602; 40 CFRpt. 63, subp. ZZZZ, Table 2c;Minn. R. 7011.8150

If an emergency engine is operating during an emergency and it is not possible toshut down the engine in order to perform the work practice requirements on theschedule required by this permit, or if performing the work practice on the requiredschedule would otherwise pose an unacceptable risk under federal, state, or locallaw, the work practice can be delayed until the emergency is over or theunacceptable risk under federal, state, or local law has abated. The work practiceshould be performed as soon as practicable after the emergency has ended or theunacceptable risk under federal, state, or local law has abated. The Permittee shallreport any failure to perform the work practice on the schedule required and thefederal, state, or local law under which the risk was deemed unacceptable.

11.0

CD 40 CFR Section 63.6605(a); Minn.R. 7011.8150

The Permittee shall be in compliance with the emission limitations and operatinglimitations in 40 CFR pt. 63, subp. ZZZZ that apply at all times.

12.0

CD 40 CFR Section 63.6605(b); Minn.R. 7011.8150

At all times the Permittee shall operate and maintain any affected source, includingassociated air pollution control equipment and monitoring equipment, in a mannerconsistent with safety and good air pollution control practices for minimizingemissions. The general duty to minimize emissions does not require the Permitteeto make any further efforts to reduce emissions if levels required by this standardhave been achieved. Determination of whether such operation and maintenanceprocedures are being used will be based on information available to theAdministrator which may include, but is not limited to, monitoring results, review ofoperation and maintenance procedures, review of operation and maintenancerecords, and inspection of the source.

13.0




12 Dec, 2014 09:18Page 9 of 73

CD 40 CFR Section 63.6625(e); Minn.R. 7011.8150

The Permittee shall operate and maintain the stationary RICE and after-treatmentcontrol device (if any) according to the manufacturer's emission-related writteninstructions or develop a maintenance plan which must provide to the extentpracticable for the maintenance and operation of the engine in a manner consistentwith good air pollution control practice for minimizing emissions.

14.0

CD 40 CFR Section 63.6625(f); Minn.R. 7011.8150

The Permittee shall install a non-resettable hour meter if one is not already installedby October 19, 2013. The non-resettable hour meter shall be maintained for the lifeof the engine.

15.0

CD 40 CFR Section 63.6625(h); Minn.R. 7011.8150

The Permittee shall minimize the engine's time spent at idle during startup andminimize the engine's startup time to a period needed for appropriate and safeloading of the engine, not to exceed 30 minutes, after which time the emissionstandards applicable to all times other than startup in 40 CFR pt. 63, subp. ZZZZ,Table 2c apply.

16.0

CD 40 CFR Section 63.6625(j); Minn.R. 7011.8150

The Permittee has the option of utilizing an oil analysis program in order to extendthe specified oil change requirement in 40 CFR pt. 63, subp. ZZZZ, Tables 2c. Theoil analysis must be performed at the same frequency specified for changing the oilin 40 CFR pt. 63, subp. ZZZZ, Table 2c. The analysis program must at a minimumanalyze the following three parameters: Total Acid Number, viscosity, and percentwater content. The condemning limits for these parameters are as follows: TotalAcid Number increases by more than 3.0 milligrams of potassium hydroxide (KOH)per gram from Total Acid Number of the oil when new; viscosity of the oil haschanged by more than 20 percent from the viscosity of the oil when new; or percentwater content (by volume) is greater than 0.5.

(continued below)

17.0

CD 40 CFR Section 63.6625(j); Minn.R. 7011.8150

(continued from above)

If none of the condemning limits are exceeded, the Permittee is not required tochange the oil. If any of the limits are exceeded, the Permittee shall change the oilwithin 2 days of receiving the results of the analysis; if the engine is not in operationwhen the results of the analysis are received, the Permittee shall change the oilwithin 2 days or before commencing operation, whichever is later. The Permitteeshall keep records of the parameters that are analyzed as part of the program, theresults of the analysis, and the oil changes for the engine. The analysis programmust be part of the maintenance plan for the engine.

18.0


The Permittee shall demonstrate continuous compliance with each emissionlimitation and operating limitation in Table 2c of 40 CFR pt. 63, subp. ZZZZ thatapply according to methods specified in Table 6 of 40 CFR pt. 63, subp. ZZZZ.

19.0

CD 40 CFR Section 63.6640(a); 40CFR pt. 63 subp. ZZZZ, Table 6;Minn. R. 7011.8150

The Permittee shall operate and maintain the stationary RICE according to themanufacturer's emission related operation and maintenance instructions; or thePermittee shall develop and follow a maintenance plan which shall provide to theextent practicable for the maintenance and operation of the engine in a mannerconsistent with good air pollution control practice for minimizing emissions.

20.0

CD 40 CFR Section 63.6665; 40 CFRpt. 63, subp. ZZZZ, Table 8; Minn.R. 7011.8150

The Permittee shall comply with the General Provisions in 40 CFR Section 63.1through 63.15, as applicable.

21.0

CD Hdr NESHAP SUBPART ZZZZ REQUIREMENTS FOR EMERGENCY STATIONARYRICE

22.0


The Permittee shall operate the engines in GP001 according to the requirements in40 CFR Section 63.6640(f)(1), (2)(i) and (3). In order for the engine to beconsidered an emergency stationary RICE under 40 CFR pt. 63, subp. ZZZZ, anyoperation other than emergency operation, maintenance and testing, and operationin non-emergency situations for 50 hours per year, as described in paragraphs 40CFR Section 63.6640(f)(1), (2)(i) and (3), is prohibited. If the engine is not operatedaccording to the requirements in 40 CFR Section 63.6640(f)(1), (2)(i) and (3), theengine will not be considered an emergency engine under 40 CFR pt. 63, subp.ZZZZ and must meet all requirements for non-emergency engines.

23.0

CD 40 CFR Section 63.6640(f)(1);Minn. R. 7011.8150

There is no time limit on the use of emergency stationary RICE in emergencysituations.

24.0

LIMIT 40 CFR Section 63.6640(f)(2);Minn. R. 7011.8150

Operating Hours: less than or equal to 100 hours/year for any combination of thepurposes specified in 40 CFR Section 63.6640(f)(2)(i) for a maximum of 100 hoursper calendar year. Any operation for non-emergency situations as allowed by 40CFR Section 63.6640(f)(3) counts as part of the 100 hours per calendar yearallowed by 40 CFR Section 63.6640(f)(2).

25.0




12 Dec, 2014 09:18Page 10 of 73

CD 40 CFR Section 63.6640(f)(2)(i);Minn. R. 7011.8150

Emergency stationary RICE may be operated for maintenance checks andreadiness testing, provided that the tests are recommended by federal, state orlocal government, the manufacturer, the vendor, the regional transmissionorganization or equivalent balancing authority and transmission operator, or theinsurance company associated with the engine. The Permittee may petition theAdministrator for approval of additional hours to be used for maintenance checksand readiness testing, but a petition is not required if the Permittee maintainsrecords indicating that federal, state, or local standards require maintenance andtesting of emergency RICE beyond 100 hours per calendar year.

26.0

LIMIT 40 CFR Section 63.6640(f)(3);Minn. R. 7011.8150

Operating Hours: less than or equal to 50 hours/year for non-emergency situations.The 50 hours of operation in non-emergency situations are counted as part of the100 hours per calendar year for maintenance and testing and emergency demandresponse provided in 40 CFR Section 63.6640(f)(2). The 50 hours per year fornon-emergency situations cannot be used for peak shaving or non-emergencydemand response, or to generate income for a facility to supply power to an electricgrid or otherwise supply power as part of a financial arrangement with anotherentity.

27.0

CD Hdr NESHAP ZZZZ RECORDKEEPING REQUIREMENTS28.0

CD 40 CFR Section 63.6655(d); Minn.R. 7011.8150

The Permittee shall keep the records required in Table 6 of 40 CFR pt. 63, subp.ZZZZ, to show continuous compliance with each emission or operating limitationthat applies.

29.0


The Permittee shall keep records of the maintenance conducted on the stationaryRICE in order to demonstrate that the Permittee operated and maintained thestationary RICE and after-treatment control device (if any) according to themaintenance plan.

30.0


The Permittee shall keep records of the hours of operation of the engine that arerecorded through the non-resettable hour meter. The Permittee shall documenthow many hours are spent for emergency operation; including what classified theoperation as emergency and how many hours are spent for non-emergencyoperation.

31.0

CD 40 CFR Section 63.6660; 40 CFRSection 63.10(b)(1); Minn. R.7011.8150; Minn. R. 7019.0100,subp. 2(B)

The Permittee shall maintain all records in a form suitable and readily available forexpeditious review according to 40 CFR Section 63.10(b)(1).

As specified in 40 CFR Section 63.10(b)(1), the Permittee shall keep each recordfor 5 years following the date of each occurrence, measurement, maintenance,corrective action, report, or record.

The Permittee shall keep each record readily accessible in hard copy or electronicform for at least 5 years after the date of each occurrence, measurement,maintenance, corrective action, report, or record, according to 40 CFR section63.10(b)(1).

32.0

CD Hdr NESHAP SUBPART ZZZZ REPORTING AND NOTIFICATION REQUIREMENTS33.0


The Permittee shall report each instance in which the stationary RICE did not meeteach applicable emission limitation or operating limitation. These instances aredeviations from the emission and operating limitations. These deviations shall bereported according to the requirements in 40 CFR Section 63.6650.

34.0


The Permittee shall report each instance in which the requirements of Table 8 in 40CFR pt. 63, subp. ZZZZ were not met.

35.0

CD Hdr GENERAL PROVISIONS - 40 CFR PT. 63, SUBP. A36.0

CD 40 CFR Section 63.4(b); Minn. R.7011.7000

Circumvention: The Permittee shall not build, erect, install, or use any article,machine, equipment, or process to conceal an emission that would otherwiseconstitute noncompliance with a relevant standard. Such concealment includes, butis not limited to:1) The use of diluents to achieve compliance with a relevant standard based on theconcentration of a pollutant in the effluent discharged to the atmosphere or2) The use of gaseous diluents to achieve compliance with a relevant standard forvisible emissions.

37.0

CD 40 CFR Section 63.5(b)(3); Minn.R. 7011.7000

Prior to construction or reconstruction of a major-emitting "affected source" underthe promulgated MACT standards, the Permittee shall apply for and obtain an airemission permit.

38.0

CD 40 CFR Section 63.9(j); Minn. R.7019.0100

Notification of information change. Any change in the information already providedunder 40 CFR Section 63.9 shall be provided to the Administrator in writing within15 calendar days after the change.

39.0




12 Dec, 2014 09:18Page 11 of 73

CD 40 CFR Section 63.10(b)(1); Minn.R. 7019.0100, subp. 2(B); Minn.R. 7019.0100

General recordkeeping requirements. The Permittee shall maintain files of allinformation (including all reports and notifications) required by 40 CFR pt. 63 in aform suitable and readily available for expeditious inspection and review. The filesshall be retained for at least 5 years following the date of each occurrence,measurement, maintenance, corrective action, report, or record. At a minimum, themost recent 2 years of data must be retained on site.

40.0

CD 40 CFR Section 63.10(b)(2)(xiv);Minn. R. 7019.0100, subp. 2(B)

General recordkeeping requirements. For each affected source, the Permittee shallmaintain the relevant records of - All documents supporting initial notifications and notifications of compliancestatus.

41.0

CD 40 CFR Section 63.10(d)(1); Minn.R. 7019.0100

Notwithstanding the requirements in 40 CFR Sections 63.10(d) and 63.10(e), thePermittee shall submit reports to the Administrator in accordance with the reportingrequirements in the relevant standard.

42.0




12 Dec, 2014 09:18Page 12 of 73

Subject Item: GP 002 Existing, CI, > 500 Hp, Emergency Engines

Associated Items: EU 027 Diesel Generator 224 - Reciprocating IC Engine

EU 032 Diesel Generator 243 - Reciprocating IC Engine









NC/CA



1.0

CD Hdr EMISSION LIMITS - MINN STANDARDS OF PERFORMANCE2.0

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

3.0


4.0

CD Minn. R. 7005.0100, subp. 35a Fuel type: No. 2 fuel oil only by design.5.0

CD Minn. R. 7007.0800, subp. 5 The Permittee shall keep records of hours of operation, fuel type and usage on amonthly basis.

6.0

CD Minn. R. 7007.0800, subps. 4 & 5 Hours of Operation: Maintain documentation on site that the unit is an emergencydiesel generator by design that qualifies under the U.S. EPA memorandum entitled"Calculating Potential to Emit (PTE) for Emergency Generators" dated September6, 1995, limiting operation to 500 hours per year.

7.0

CD Minn. R. 7007.0800, subp. 2 The Permittee shall install a non-resettable hour meter if within 180 days of permitissuance one is not already installed. The non-resettable hour meter shall bemaintained for the life of the engine.

8.0

CD Hdr NESHAP SUBPART ZZZZ REQUIREMENTS9.0

CD 40 CFR Section 63.6590(b)(3)(iii);Minn. R. 7011.2300

The Permittee shall not operate or enter into a contract that requires the Permitteeto operate any of the engines in GP002 available for more than 15 hours percalendar year for the purposes specified in 40 CFR Section 63.6640(f)(2)(ii) and (iii)(Emergency demand response and voltage or frequency deviation of greater than 5percent).

10.0




12 Dec, 2014 09:18Page 13 of 73

Subject Item: GP 003 Existing, CI, <= 500 Hp, Emergency Engines




NC/CA



1.0


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

3.0


4.0

CD Minn. R. 7005.0100, subp. 35a Fuel type: No. 2 fuel oil only by design.5.0

CD Minn. R. 7007.0800, subp. 5 The Permittee shall keep records of fuel type and usage on a monthly basis.6.0


7.0

CD Hdr NESHAP SUBPART ZZZZ OPERATING REQUIREMENTS8.0


Change oil and filter every 500 hours of operation or annually, whichever comesfirst.

The Permittee has the option to utilize an oil analysis program as described later inthis permit in order to extend the specified oil change requirement.

9.0


Inspect air cleaner every 1,000 hours of operation or annually, whichever comesfirst, and replace as necessary.

10.0


Inspect all hoses and belts every 500 hours of operation or annually, whichevercomes first, and replace as necessary.

11.0


If an emergency engine is operating during an emergency and it is not possible toshut down the engine in order to perform the work practice requirements on theschedule required by this permit, or if performing the work practice on the requiredschedule would otherwise pose an unacceptable risk under federal, state, or locallaw, the work practice can be delayed until the emergency is over or theunacceptable risk under federal, state, or local law has abated. The work practiceshould be performed as soon as practicable after the emergency has ended or theunacceptable risk under federal, state, or local law has abated. The Permittee shallreport any failure to perform the work practice on the schedule required and thefederal, state, or local law under which the risk was deemed unacceptable.

12.0


The Permittee shall be in compliance with the emission limitations, operatinglimitations, and other requirements in this subpart that apply at all times.

13.0


At all times the Permittee shall operate and maintain any affected source, includingassociated air pollution control equipment and monitoring equipment, in a mannerconsistent with safety and good air pollution control practices for minimizingemissions. The general duty to minimize emissions does not require the Permitteeto make any further efforts to reduce emissions if levels required by this standardhave been achieved. Determination of whether such operation and maintenanceprocedures are being used will be based on information available to theAdministrator which may include, but is not limited to, monitoring results, review ofoperation and maintenance procedures, review of operation and maintenancerecords, and inspection of the source.

14.0


The Permittee shall operate and maintain the stationary RICE and after-treatmentcontrol device (if any) according to the manufacturer�s emission-related writteninstructions or develop a maintenance plan which must provide to the extentpracticable for the maintenance and operation of the engine in a manner consistentwith good air pollution control practice for minimizing emissions.

15.0




12 Dec, 2014 09:18Page 14 of 73


The Permittee shall install a non-resettable hour meter if one is not already installedby May 3, 2013. The non-resettable hour meter shall be maintained for the life ofthe engine.

16.0

CD 40 CFR Section 63.6602; 40 CFRpt. 63, subp. ZZZZ, Table 2c; 40CFR Section 63.6625(h); Minn. R.7011.8150

The Permittee shall minimize the engine's time spent at idle during startup andminimize the engine's startup time to a period needed for appropriate and safeloading of the engine, not to exceed 30 minutes, after which time the emissionstandards applicable to all times other than startup apply.

17.0

CD 40 CFR Section 63.6625(i); Minn.R. 7011.8150

The Permittee has the option of utilizing an oil analysis program in order to extendthe specified oil change requirement. The oil analysis shall be performed at thesame frequency specified for changing the oil. The analysis program shall at aminimum analyze the following 3 parameters: Total Base Number, viscosity, andpercent water content. The condemning limits for these parameters are as follows:Total Base Number is less than 30 percent of the Total Base Number of the oilwhen new; viscosity of the oil has changed by more than 20 percent from theviscosity of the oil when new; or percent water content (by volume) is greater than0.5.

(continued below)

18.0

CD 40 CFR Section 63.6625(i); Minn.R. 7011.8150

(continued from above)

If none of the condemning limits are exceeded, the Permittee is not required tochange the oil. If any of the limits are exceeded, the Permittee shall change the oilwithin 2 business days of receiving the results of the analysis; if the engine is not inoperation when the results of the analysis are received, the Permittee shall changethe oil within 2 business days or before commencing operation, whichever is later.The Permittee shall keep records of the parameters that are analyzed as part of theprogram, the results of the analysis, and the oil changes for the engine. Theanalysis program shall be part of the maintenance plan for the engine.

19.0

CD 40 CFR Section 63.6640(a); 40CFR Section 63.6655(d); 40 CFRpt. 63 subp. ZZZZ, Table 6; Minn.R. 7011.8150

The Permittee shall demonstrate continuous compliance with each emissionlimitation, operating limitation, and other requirements in Table 2c of 40 CFR pt. 63,subp. ZZZZ that apply according to methods specified in Table 6 of 40 CFR pt. 63,subp. ZZZZ.

The Permittee shall operate and maintain the stationary RICE according to themanufacturer's emission related operation and maintenance instructions; or thePermittee shall develop and follow a maintenance plan which shall provide to theextent practicable for the maintenance and operation of the engine in a mannerconsistent with good air pollution control practice for minimizing emissions.

20.0

CD 40 CFR Section 63.6665 andTable 8 to Subpart ZZZZ of Part63; Minn. R. 7011.8150

The Permittee shall comply with the General Provisions in 40 CFR Section 63.1through 63.15, as applicable.

21.0

CD Hdr NESHAP SUBPART ZZZZ REQUIREMENTS FOR EMERGENCY STATIONARYRICE

22.0


The Permittee shall operate the emergency stationary RICE according to therequirements in paragraphs 40 CFR Section 63.6640(f)(1), (2)(i), and (3) of 40 CFRSection 63.6640(f). Any operation other than emergency operation, maintenanceand testing, emergency demand response, and operation in non-emergencysituations for 50 hours per year, as described in 40 CFR Section 63.6640(f)(1),(2)(i), and (3), is prohibited. If the engine is not operated according to therequirements in 40 CFR Section 63.6640(f)(1), (2)(i), and (3), the engine will not beconsidered an emergency engine under this subpart and will need to meet allrequirements for non-emergency engines.

23.0

CD 40 CFR Section 63.6640(f)(1) -(2); Minn. R. 7011.8150

(1) There is no time limit on the use of emergency stationary RICE in emergencysituations.(2) The Permittee may operate the emergency stationary RICE for any combinationof the purposes specified in 40 CFR Section 63.6640(f)(2)(i) for a maximum of 100hours per calendar year. Any operation for non-emergency situations as allowed by40 CFR Section 63.6640(f)(3) counts as part of the 100 hours per calendar yearallowed by this paragraph (f)(2).

24.0




12 Dec, 2014 09:18Page 15 of 73

CD 40 CFR Section 63.6640(f)(2)(i);Minn. R. 7011.8150

The Permittee may operate the emergency stationary RICE for the purpose ofmaintenance checks and readiness testing, provided that the tests arerecommended by Federal, State or local government, the manufacturer, thevendor, the regional transmission organization or equivalent balancing authorityand transmission operator, or the insurance company associated with the engine.The Permittee may petition the Administrator for approval of additional hours to beused for maintenance checks and readiness testing, but a petition is not required ifthe Permittee maintains records indication that Federal, State, or local standardsrequire maintenance and testing of emergency RICE beyond 100 hours per year.

25.0


The Permittee may operate the emergency stationary RICE up to 50 hours percalendar year in non-emergency situations, but those 50 hours are countedtowards the 100 hours per calendar year provided for maintenance and testing andemergency demand response provided in 40 CFR Section 63.6640(f)(2). The 50hours per year for non-emergency situations cannot be used for peak shaving ornon-emergency demand response, or to generate income for a facility to supplypower to an electric grid or otherwise supply power as part of a financialarrangement with another entity.

26.0

CD Hdr NESHAP SUBPART ZZZZ RECORDKEEPING REQUIREMENTS27.0


The Permittee shall keep the records required in Table 6 of 40 CFR pt. 63, subp.ZZZZ, to show continuous compliance with each emission or operating limitationthat applies.

28.0


The Permittee shall keep records of the maintenance conducted on the stationaryRICE in order to demonstrate that the Permittee operated and maintained thestationary RICE and after-treatment control device (if any) according to themaintenance plan.

29.0


The Permittee shall keep records of the hours of operation of the engine that arerecorded through the non-resettable hour meter. The Permittee shall documenthow many hours are spent for emergency operation; including what classified theoperation as emergency and how many hours are spent for non-emergencyoperation.

30.0

CD 40 CFR Section 63.6660; 40 CFRSection 63.10(b)(1); Minn. R.7011.8150; Minn. R. 7019.0100,subp. 2(B)

The Permittee shall maintain all records in a form suitable and readily available forexpeditious review according to 40 CFR Section 63.10(b)(1).

As specified in 40 CFR Section 63.10(b)(1), the Permittee shall keep each recordfor 5 years following the date of each occurrence, measurement, maintenance,corrective action, report, or record.

The Permittee shall keep each record readily accessible in hard copy or electronicform for at least 5 years after the date of each occurrence, measurement,maintenance, corrective action, report, or record, according to 40 CFR section63.10(b)(1).

31.0

CD Hdr GENERAL PROVISIONS - 40 CFR PT. 63, SUBP. A32.0


Circumvention: The Permittee shall not build, erect, install, or use any article,machine, equipment, or process to conceal an emission that would otherwiseconstitute noncompliance with a relevant standard. Such concealment includes, butis not limited to:1) The use of diluents to achieve compliance with a relevant standard based on theconcentration of a pollutant in the effluent discharged to the atmosphere or2) The use of gaseous diluents to achieve compliance with a relevant standard forvisible emissions.

33.0

CD 40 CFR Section 63.5(b)(3); Minn.R. 7011.7000

Prior to construction or reconstruction of a major-emitting "affected source" underthe promulgated MACT standards, the Permittee shall apply for and obtain an airemission permit.

34.0

CD 40 CFR Section 63.9(j); Minn. R.7019.0100

Notification of information change. Any change in the information already providedunder 40 CFR Section 63.9 shall be provided to the Administrator in writing within15 calendar days after the change.

35.0

CD 40 CFR Section 63.10(b)(1); Minn.R. 7019.0100, subp. 2(B); Minn.R. 7019.0100

General recordkeeping requirements. The Permittee shall maintain files of allinformation (including all reports and notifications) required by 40 CFR pt. 63 in aform suitable and readily available for expeditious inspection and review. The filesshall be retained for at least 5 years following the date of each occurrence,measurement, maintenance, corrective action, report, or record. At a minimum, themost recent 2 years of data must be retained on site.

36.0




12 Dec, 2014 09:18Page 16 of 73

CD 40 CFR Section 63.10(b)(2)(xiv);Minn. R. 7019.0100, subp. 2(B)

General recordkeeping requirements. For each affected source, the Permittee shallmaintain the relevant records of - All documents supporting initial notifications and notifications of compliancestatus.

37.0

CD 40 CFR Section 63.10(d)(1); Minn.R. 7019.0100

Notwithstanding the requirements in 40 CFR Sections 63.10(d) and 63.10(e), thePermittee shall submit reports to the Administrator in accordance with the reportingrequirements in the relevant standard.

38.0




12 Dec, 2014 09:18Page 17 of 73

Subject Item: GP 004 New, CI > 500 Hp, Emergency Engines




EU 051 Emergency Generator Bldg 217 - Reciprocating IC Engine

EU 054 Emergency Generator Bldg 217 EU012 Replacement Generator - Reciprocating IC Engine

EU 055 Diesel Emergency Generator Bldg 280 - Reciprocating IC Engine

NC/CA



1.0

CD hdr EMISSION LIMITS - MINN STANDARDS OF PERFORMANCE2.0

LIMIT Minn. R. 7011.2300, subp. 1 Opacity: less than or equal to 20.0 percent opacity once operating temperatureshave been attained.

3.0


CD Minn. R. 7007.0800, subp. 5 The Permittee shall keep records of hours of operation, fuel type and usage on amonthly basis.

5.0

CD Minn. R. 7007.0800, subps. 4 & 5 Hours of Operation: The Permittee shall maintain documentation on site that theunit is an emergency generator by design that qualifies under the U.S. EPAmemorandum entitled "Calculating Potential to Emit (PTE) for EmergencyGenerators" dated September 6, 1995, limiting operation to 500 hours per year.

6.0


7.0

CD hdr OPERATING REQUIREMENTS - NESHAP SUBP. ZZZZ8.0

CD 40 CFR Section 63.6590(b)(1)(i);Minn. R. 7011.8150

The Permittee shall not operate or enter into a contract that requires the Permitteeto operate any engine in GP004 for the purposes specified in 40 CFR Section63.6640(f)(2)(ii) and (iii). (More than 15 hours per calendar year for emergencydemand response and voltage or frequency deviation of greater than 5 percent)

9.0


Initial Notification: The Permittee shall submit an initial notification to theCommissioner in writing that the source is subject to 40 CFR pt. 63, subp. ZZZZ nolater than 120 after the effective date of the standard. The notification shall includethe information in 40 CFR pt. 63.9(b)(2)(i) through (v), and a statement that thestationary RICE has no additional requirements and explain the basis of theexclusion (for example, the RICE operates exclusively as an emergency stationaryRICE, has a site rating of greater than 500 brake HP and is located at a majorsource of HAP emissions).

3M - Administrative Offices - Maplewood completed this requirement.

10.0




12 Dec, 2014 09:18Page 18 of 73

Subject Item: GP 005 New, <= 500 Hp, Emergency Engines

Associated Items: EU 048 Emergency Generator #1 Bldg 220 - Reciprocating IC Engine

EU 049 Emergency Generator #2 Bldg 220 - Reciprocating IC Engine

EU 050 Diesel Fire Pump Bldg 217 - Reciprocating IC Engine



NC/CA



1.0




4.0

CD Minn. R. 7007.0800, subp. 5 The Permittee shall keep records of fuel type and usage on a monthly basis.5.0


6.0


7.0

CD Hdr NESHAP REQUIREMENTS8.0

CD 40 CFR Section 63.6590(c); Minn.R. 7011.8150

The engines in GP005 shall meet the requirements of 40 CFR pt. 63, subp. ZZZZby meeting the requirements of 40 CFR pt. 60, subp. IIII or subp. JJJJ.

Applicable requirements from 40 CFR pt. 60, subp. IIII or subp. JJJJ for the enginesin this group are located at the individual EU level.

9.0




12 Dec, 2014 09:18Page 19 of 73

Subject Item: GP 006 Building 243 Engines






NC/CA



No more than 3 generators at Building 243 (EU032, EU033, EU034, EU035 andEU036) may be operated at one time.

1.0


Operating Records: The Permittee shall maintain daily on-site records during theoperation of any generator in GP006. The record shall include:1. The name of the generator that is operating;2. The date, time and duration of operation; and3. The names of other generators in GP006, if any, that operates within the sameperiod of operation.

The records may be maintained in a written log or electronic format.

2.0




12 Dec, 2014 09:18Page 20 of 73

Subject Item: GP 011 Best Management Practices for Emergency Engines

Associated Items: EU 008 NG Generator 201 - Reciprocating IC Engine
























EU 050 Diesel Fire Pump Bldg 217 - Reciprocating IC Engine




EU 054 Emergency Generator Bldg 217 EU012 Replacement Generator - Reciprocating IC Engine

EU 055 Diesel Emergency Generator Bldg 280 - Reciprocating IC Engine

NC/CA


CD hdr BEST MANAGEMENT PRACTICES1.0

CD Minn. R. 7007.0800, subp. 2 The Permittee shall comply with the engine best management practices (BMPs)defined in this permit for all emergency engines, including existing, modified or newemergency engines. These requirements apply to each engine in GP011individually. Engines added by a minor or moderate amendments are subject to therequirements of GP011.

2.0




12 Dec, 2014 09:18Page 21 of 73

CD Minn. R. 7007.0800, subps. 2, 4and 5

The Permittee shall only use diesel fuel with a sulfur content of less than or equal to15 ppm or natural gas in the emergency engines.

The Permittee may not install a rain cap on any of the emergency engine stacks.

The Permittee shall make the test runs for each engine as short as allowed byinsurance and building code considerations.

The testing for an emergency engine shall not occur while another emergencyengine is being tested.

No testing shall be conducted on a day that the Air Quality Index (AQI) or theforecasted AQI exceeds 90 unless the test cannot be deferred. For testingconducted on a day with the AQI above 90, document the reason it was notpossible to defer the test and any actions that were taken to limit emissions duringthe test with the testing records.

The AQI and the forecasted AQI can be found athttp://www.pca.state.mn.us/index.php/air/air-quality-and-pollutants/general-air-qualit

3.0


During every test of each emergency engine, record the following information:The unit that is tested;The date;The time the test started;The time the test was completed; andThe Air Quality Index (AQI).

4.0




12 Dec, 2014 09:18Page 22 of 73

Subject Item: GP 012 CEMS and COMS - NSPS Db

Associated Items: EU 006 Boiler 6 210-B06 - Boiler

EU 043 Boiler No. 7 - Boiler

MR 001 NOx

MR 002 Opacity

MR 003 Diluent O2

MR 004 NOx

MR 005 CO

MR 006 Opacity

MR 007 Diluent O2

SV 006 Boiler 6 210-B06

SV 043 Boiler 7, 210-B07 [1]

NC/CA


CD hdr CEMS REQUIREMENTS1.0

CD 40 CFR Section 60.48b(b)(1);Minn. R. 7017.1010, subp. 1

Emissions Monitoring: The owner or operator shall use a NOx CEMS to measureNOx emissions from EU006/SV006. Additional monitoring requirements are alsolocated at the individual MR level.

2.0

CD 40 CFR Section 60.48b(b)(1);Minn. R. 7017.1010, subp. 1

Emissions Monitoring: The owner or operator shall use a NOx CEMS to measureNOx emissions from EU043/SV043. Additional monitoring requirements are alsolocated at the individual MR level.

3.0

CD 40 CFR Section 60.13(e)(2); Minn.R. 7017.1140; Minn. R.7017.1010, subp. 1

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

4.0

CD Minn. R. 7017.1040, subp. 1 Installation Notification: due 60 days before CEMS installation. The notificationshall include plans and drawings of the system.

3M - Administrative Offices - Maplewood has completed this requirement. Monitorswere installed on the following dates:EU006/MR001 (NOx): 2/1/1993EU006/MR003 (O2): 10/15/2006EU043/MR004 (NOx): 10/15/2006EU043/MR005 (CO): 10/15/2006EU043/MR007 (O2): 10/15/2006

5.0

CD 40 CFR Section 60.13(b); Minn. R.7017.1050, subp. 1; Minn. R.7017.1010

CEMS Certification/Recertification Test: due 120 days after the first calendarquarter following CEMS Installation. (This requirement is as stringent as that of Minn. R. 7017.1050, subp. 1 requiringtesting within 90 days after the due date of the first excess emissions reportrequired for the CEMS or COMS).

A recertification test of a previously certified continuous monitoring system is notrequired unless the monitor has undergone a change which invalidates itscertification.

6.0

CD 40 CFR Section 60.7(a)(5); Minn.R. 7017.1060, subps. 1-3; Minn.R. 7017.1080, subp. 1-4; Minn. R.7019.0100

CEMS Certification Test Plan: due 30 days before CEMS Certification Test.CEMS Certification Test Pretest Meeting: due 7 days before CEMS CertificationTest CEMS Certification Test Report: due 45 days after CEMS Certification TestCEMS Certification Test Report - Microfiche Copy: due 105 days after CEMSCertification Test

The Test plan shall contain all of the information required by Minn. R. 7017.1060,subp. 2.

The Test Report shall contain all of the information required by Minn. R. 7017.1080,subp. 4.

The Notification, Test Plan, and Test Report may be submitted in alternate formatas allowed by Minn. R. 7017.1120, subp. 2

7.0




12 Dec, 2014 09:18Page 23 of 73

CD 40 CFR Section 60.13(e); Minn. R.7017.1090; Minn. R. 7017.1010,subp. 1

Continuous Operation: CEMS must be operated and data recorded during allperiods of emission unit operation including periods of emission unit start-up,shutdown, or malfunction except for periods of acceptable monitor downtime. Thisrequirement applies whether or not a numerical emission limit applies during theseperiods. A CEMS must not be bypassed except in emergencies where failure tobypass would endanger human health, safety, or plant equipment.

8.0

CD 40 CFR Section 60.48b(f); Minn.R. 7011.0565

Comply with the provisions of 40 CFR pt. 60, subp. Db with respect to NOx CEMSoperation. When NOx emission data are not obtained because of CEMSbreakdowns, repairs, calibration checks and zero and span adjustments, obtaindata using standby monitoring systems, Method 7 of 40 CFR pt. 60, appendix A,Method 7A of 40 CFR pt. 60, appendix A, or other approved reference methods toprovide data for a minimum of 75 percent of the operating hours in each steamgenerating unit operating day, in at least 22 out of 30 successive steam generatingunit operating days.

9.0

CD 40 CFR pt. 60, Appendix F;Section 3; Minn. R. 7017.1170,subp. 2

QA Plan: Develop and implement a written quality assurance plan that covers eachCEMS. The plan shall be on site and available for inspection within 30 days aftermonitor certification. The plan shall be revised as needed in order to keep it up todate with the facility's current policies and procedures. The plan shall contain all ofthe information required by 40 CFR Part 60, Appendix F, Section 3. The plan shallinclude the manufacturer's spare parts list for each CEMS and require that thoseparts be kept at the facility unless the Commissioner gives written approval toexclude specific spare parts from the list.

10.0

CD 40 CFR pt. 60, Appendix F; 40CFR Section 60.13(a); Minn. R.7017.1010, subp. 1

CEMS QA/QC: The owner or operator of an affected facility is subject to theperformance 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 CFRpt. 60, Appendix F as amended and maintain a written QA/QC program available ina form suitable for inspection.

11.0


Recordkeeping: The Permittee shall maintain records of the occurrence andduration of any startup, shutdown, malfunction, or any periods during which acontinuous monitoring system or monitoring device is inoperative.

12.0

CD 40 CFR Section 60.7(f); Minn. R.7017.1130; Minn. R. 7019.0100

Recordkeeping: The Permittee shall maintain a file of all of the following CEMSinformation at the emission facility in a form suitable for inspection for at least fiveyears from the date of each record: each one-hour emission average recorded bythe CEMS; monitor certification test reports; excess emissions reports; cylinder gasaudit reports; calibration error audit reports; relative accuracy test audits; linearitycheck reports; results of daily calibration drift cheks; log of adjustments made to theCEMS and maintenance performed on the CEMS; and all other monitoring systeminformation required by an applicable compliance document. The Permittee shallalso keep an updated copy of the facility's CEMS quality assurance plans on site.

13.0

CD 40 CFR Section 60.13(h); Minn. R.7017.1010, subp. 1

Monitoring Data: Reduce all NSPS-required continuous monitoring systems otherthan COMS data to time periods as defined in 40 CFR Section 60.2, in accordancewith 40 CFR Section 60.13(h).

14.0

CD hdr COMS REQUIREMENTS15.0

CD 40 CFR Section 60.48b(a); Minn.R. 7017.1006

Emissions Monitoring: The owner or operator shall use a COMS to measureOpacity from EU006/SV006. Additional monitoring requirements are also located atthe individual MR level (MR002).

16.0

CD 40 CFR Section 60.48b(a); Minn.R. 7017.1006

Emissions Monitoring: The owner or operator shall use a COMS to measureOpacity from EU043/SV043. Additional monitoring requirements are also located atthe individual MR level (MR006).

17.0

CD 40 CFR Section 60.13(d)(2); Minn.R. 7010.1010, subp. 1

Unless otherwise approved by the Administrator, the following procedures must befollowed for a COMS. Minimum procedures must include an automated method forproducing a simulated zero opacity condition and an upscale opacity conditionusing a certified neutral density filter or other related technique to produce a knownobstruction of the light beam. Such procedures must provide a system check of allactive analyzer internal optics with power or curvature, all active electronic circuitryincluding the light source and photodetector assembly, and electronic orelectro-mechanical systems and hardware and or software used during normalmeasurement operation.

18.0

CD 40 CFR Section 60.13(e)(1); Minn.R. 7017.1190; Minn. R.7010.1010, subp. 1

COMS Monitor Design: Each COMS shall be designed to complete a minimum ofone cycle of sampling and analyzing in each successive ten-second period and onecycel of data recording each one-minute period.

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12 Dec, 2014 09:18Page 24 of 73

CD 40 CFR Section 60.13(h)(1); Minn.R. 7017.1200, subp. 1, 2, & 3;Minn. R. 7017.1010, subp. 1

Monitoring Data: All COMS data must be reduced to six-minute averages for timeperiods as defined in 40 CFR 60.2. Compliance must be calculated from all datapoints collected in the averaging period by the COMS. A six-minute average is validonly if it contains data from at least five of the minutes within the averaging period.Six minute averages shall be calculated following the procedures in Minn. R.7017.1200, subp. 3.

Six-minute opacity averages shall be calculated from 36 or more data pointsequally spaced over each 6-minute period.

20.0

CD 40 CFR Section 60.13(e)(1); Minn.R. 7017.1010, subp. 1

Except for system breakdowns, repairs, calibration checks, and zero and spanadjustments required under 40 CFR Section 60.13(d), all continuous monitoringsystems shall be in continuous operation.

All COMS shall complete a minimum of one cycle of sampling and analyzing foreach successive 10-second period and one cycle of data for each successive6-minute period.

21.0

CD Minn. R. 7017.1040, subp. 1 Installation Notification: due 60 days before COMS installation. The notificationshall include plans and drawings of the system.

3M - Administrative Offices - Maplewood has completed this requirement. Monitorswere installed on the following dates:EU006/MR002 (Opacity): 10/15/2006EU043/MR006 (Opacity): 10/15/2006

22.0

CD Minn. R. 7017.1050, subp. 1 COMS Certification Test: due 120 days after the first calendar quarter followingCEMS Installation. (This requirement is as stringent as that of Minn. R. 7017.1050,subp. 1 requiring testing within 90 days after the due date of the first excessemissions report required for the CEMS or COMS. If necessary, the COMSCertification test may be completed at the same time as the 40 CFR pt. 60performance evaluation provided all applicable deadlines are met.)

23.0

CD 40 CFR Section 60.13(c); Minn. R.7017.1010, subp. 1

NSPS COMS Performance Evaluation: Due before the performance test requiredunder 40 CFR Section 60.8 is conducted as specified in Performance Specification1, Appendix B of 40 CFR pt. 60. Otherwise, during any performance test requiredunder Section 60.8 or within 30 days thereafter. The owner or operator of anaffected facility shall conduct COMS or CEMS performance evaluations at suchother times as may be required by the Administrator under Section 114 of theClean Air Act. (Provided all applicable deadlines are met, the performanceevaluation may be completed at the same time as the Minn. R. requiredCertification Test.)

24.0

CD 40 CFR Section 60.7(a)(5); Minn.R. 7017.1060, subp. 1-3; Minn. R.7017.1080, subp. 1-4; Minn. R.7019.0100

COMS Certification Test Plan: due 30 days before COMS Certification Test

COMS Certification Test Pretest Meeting: due 7 days before COMS CertificationTest

COMS Certification Test Report: due 45 days after COMS Certification Test

COMS Certification Test Report - Microfiche Copy: due 105 days after COMSCertification Test

The Test plan shall contain all of the information required by Minn. R. 7017.1060,subp. 2.

The Test Report shall contain all of the information required by Minn. R. 7017.1080,subp. 4.

The Notification, Test Plan, and Test Report may be submitted in alternate formatas allowed by Minn. R. 7017.1120, subp. 2

25.0

CD 40 CFR Section 60.13(e); Minn. R.7017.1090; Minn. R. 7017.1010

Continuous Operation: COMS must be operated and data recorded during allperiods of emission unit operation including periods of emission unit start-up,shutdown, or malfunction except for periods of acceptable monitor downtime. Thisrequirement applies whether or not a numerical emission limit applies during theseperiods. A COMS must not be bypassed except in emergencies where failure tobypass would endanger human health, safety, or plant equipment.

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12 Dec, 2014 09:18Page 25 of 73

CD Minn. R. 7017.1210, subp. 1 QA Plan: Develop and implement a written quality assurance plan that covers eachCOMS. The plan shall be on site and available for inspection within 30 days aftermonitor certification. The plan shall be revised as needed in order to keep it up todate with the facility's current policies nad procedures. The plan shall contain all ofthe information required by Minn. R. 7017.1210, subp. 1. The plan shall include themanufacturer's spare parts list for each COMS and require that those parts be keptat the facility unless the Commissioner gives written approval to exclude specificspare parts from the list.

27.0

CD 40 CFR pt. 60, Appendix B.Section 7; Minn. R. 7017.1210,subp. 4

COMS Attenuator Calibration: The Permittee shall semiannually have anindependent testing company conduct calibrations of each of the neutral densityfilters used in the calibration error audit according to the procedure in 40 CFR pt.60, Appendix B, section7.1.3. The manufacturer's guarantee of stability shall be onsite available for inspection.

28.0

CD Minn. R. 7017.1130 Recordkeeping: The Permittee shall maintain a file of all of the following COMSinformation at the emission facility in a form suitable for inspection for at least fiveyears from the date of each record: each six-minute opacity average recorded bythe COMS; monitor certification test reports; excess emissions reports; cylinder gasaudit reports; calibration error audit reports; relative accuracy test audits; linearitycheck reports; results of daily calibration drift cheks; log of adjustments made to theCOMS and maintenance performed on the COMs; and all other monitoring systeminformation required by an applicable compliance document. The Permittee shallalso keep an updated copy of the facility's COMS quality assurance plans on site.

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12 Dec, 2014 09:18Page 26 of 73

Subject Item: EU 003 Boiler 3 210-B03 - Boiler

Associated Items: SV 003 Boiler 3 210-B03

NC/CA


LIMIT Minn. R. 7011.0510, subp. 1 Total Particulate Matter: less than or equal to 0.40 lbs/million Btu heat input .1.0

LIMIT Minn. R. 7011.0510, subp. 2 Opacity: less than or equal to 20 percent opacity except for one six-minute periodper hour of not more than 60 percent opacity.

2.0

CD Minn. R. 7007.0800, subp. 2 Fuels allowed: natural gas only3.0

CD hdr NESHAP Subpart DDDDD REQUIREMENTS for Major Sources: Industrial,Commercial, and Institutional Boilers and Process Heaters

4.0

CD 40 CFR Section 63.7485; 40 CFRSection 63.7490; 40 CFR Section63.7495(b); Minn. R. 7011.

The Permittee shall comply with the requirements of National Emission Standardsfor Hazardous Air Pollutants for Industrial, Commercial, and Institutional Boilersand Process Heaters, 40 CFR pt. 63, subp. DDDDD, if applicable, as specifiedunder 40 CFR Section 63.7490, by the applicable deadlines as specified under 40CFR Section 63.7495. Compliance date for existing sources is January 31, 2016 oras subsequently modified by applicable regulatory amendment or judicial order.

5.0

CD 40 CFR Section 63.7500(e); 40CFR pt. 63, subp. DDDDD, Table3

The Permittee shall complete a tune-up of EU003 annually as specified in 40 CFRSection 63.7540. Boilers and process heaters in the units designed to burn gas 1fuels subcategory are not subject to the emission limits in Tables 1 and 2 or 11through 13, or the operating limits in Table 4 of 40 CFR pt. 63, subp. DDDDD.

6.0

CD 40 CFR Section 63.7530(d); 40CFR Section 63.7530(e)

The Permittee shall submit a signed statement in the Notification of ComplianceStatus report that indicates that the tune-up of EU003 was conducted.

The Permittee shall submit a signed statement in the Notification of ComplianceStatus report that indicates that the energy assessment was completed accordingto 40 CFR pt. 63, subp. DDDDD, Table 3 and that it is an accurate depiction of the3M - Maplewood facility at the time of the assessment.

7.0

CD 40 CFR Section 63.7540(a)(12);40 CFR Section63.7540(a)(10)(i)-(vi)

Boiler Tune-Up requirements: The Permittee shall:1. Inspect the burner, and clean or replace any components of the burner asnecessary (the burner inspection may be delayed until the next scheduled unitshutdown).2. Inspect the flame pattern, as applicable, and adjust the burner as necessary tooptimize the flame pattern. The adjustment should be consistent with themanufacturer's specifications, if available.3. Inspect the system controlling the air-to-fuel ratio, as applicabe, and ensure thatit is correctly calibrated and functioning properly (the inspection may be delayeduntil the next scheduled shutdown).4. Optimize total emissions of CO. This optimization should be consistent with themanufacturer's specifications, if available, and with any NOx requirement to whichthe unit is subject.

8.0


Boiler Tune-Up requirements continued: The Permittee shall:5. Measure the concentrations in the effluent stream of CO in parts per million, byvolume, and oxygen in volume percent, before and after the adjustments are made(measurements may be either on a dry or we basis, as long as it is the same basisbeore and after the adjustments are made). Measurements may be taken using aportable CO analyzer.6. Maintain on-site and submit, if requested by the Administrator or Commissioner,an annual report containing the the following information:a. The concnetrations of CO in the effluen stream in parts per million by volume,and in oxygen volume percent, measured at high fire or typical operating load,before and after the tune-up of the boiler.b. A description of any corrective actions taken as a part of the tune-up.

9.0

CD 40 CFR Section 63.7545(a); 40CFR Section 63.9(b)(2); Minn. R.7019.0100

The Permittee shall submit to the Administrator or Commissioner the InitialNotification required by 40 CFR Section 63.9(b)(2) and the Notification ofCompliance Status required by 40 CFR Section 63.9(h) that apply by the datesspecified.

3M - Administrative Offices - Maplewood completed the Initial Notificationrequirement.

10.0




12 Dec, 2014 09:18Page 27 of 73

CD 40 CFR Section 63.7545(e); 40CFR Section 63.9(h)(2)(ii); Minn.R. 7019.0100

The Permittee shall submit a Notification of Compliance Status according to 40CFR Section 63.9(h)(2)(ii), if applicable. For the initial compliance demonstrationfor each boiler or process heater, the Permittee shall submit the Notification ofCompliance Status, including all performance test results and fuel analyses, beforethe close of business on the 60th day following the completion of all performancetest and/or other initial compliance demonstrations for all boiler or process heatersat the facility according to 40 CFR Section 63.10(d)(2). The Notification ofCompliance Status report shall contain all the information specified in 40 CFRSection 63.7545(e)(1) through (8), as applicable.

11.0

CD 40 CFR Section 63.7550(a), (b),and (h)

The Permittee shall submit the Compliance Report meeting the requirements of 40CFR pt. 63, subp. DDDDD, Table 9.

The Permittee shall submit the Compliance Report according to 40 CFR Section63.7550(h) by the date in 40 CFR pt. 63, subp. DDDDD, Table 9 and according tothe requirements in 40 CFR Section 63.7550(b)(1) through (4). The Permittee maysubmit only an annual compliance report instead of a semi-annual compliancereport.

The Permittee shal submit all reports required by 40 CFR pt. 63, subp. DDDDD,Table 9 electronically using CEDRI that is accessed through the EPA's CentralData Exchange (CDX) (www.epa.gov/cdx). However, if the reporting form specificto this subpart is not available in CEDRI at the time that the report is due the thereprot shall be submitted to the Administrator at the appropriate address listed in 40CFR Section 63.13.

12.0

CD 40 CFR Section 63.7555(a) The Permittee shall keep records according to the following:1. A copy of each notification and report that was submitted to comply with 40 CFRpt. 63, subp. DDDDD, including all documentation supporting and Initial Notificationor Notification of Compliance Status or semiannual compliance report that wassubmitted, according to the requirements of 40 CFR Section 63.10(b)(2)(xiv).2. Records of performance tests, fuel analyses, or other compliancedemonstrations and performance evaluations as required in 40 CFR Section63.10(b)(2)(viii).

13.0

CD 40 CFR Section 63.7560(a)-(c); 40CFR Section 63.10(b); Minn. R.7019.0100

The Permittee shall keep records in a suitable format and readily available forexpeditious review, according to 40 CFR Section 63.10(b)(1).

The Permittee shall keep each record for 5 years following the date of eachoccurrence, measurement, maintenance, corrective action, report or record.

The Permittee shall keep each record on site, or they must be accessible from onsite (for example through a computer network), for at least 2 years after the date ofeach occurrence, measurement, maintenance, corrective action, report, or record,according to 40 CFR Section 63.10(b)(1). Records maybe kept off site for theremaining 3 years.

14.0


The Permittee shall not build, erect, install, or use any article, machine, equipment,or process to conceal an emission that would otherwise constitute noncompliancewith 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 theconcentration of a pollutant in the effluent discharged to the atmosphere;

2. The use of gaseous diluents to achieve compliance with a relevant standard forvisible emissions.

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12 Dec, 2014 09:18Page 28 of 73



NC/CA




2.0



4.0



5.0



6.0



The Permittee shall submit a signed statement in the Notification of ComplianceStatus report that indicates that the energy assessment was completed accordingto 40 CFR pt. 63, subp. DDDDD, Table 3 and that it is an accurate depcition of the3M - Maplewood facility at the time of the assessment.

7.0



8.0



9.0



3M - Administrative Offices - Maplewood completed the Initial Notificationrequirement on 5/20/2013.

10.0




12 Dec, 2014 09:18Page 29 of 73



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12.0


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12 Dec, 2014 09:18Page 30 of 73



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2.0



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12 Dec, 2014 09:18Page 31 of 73



11.0





12.0


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12 Dec, 2014 09:18Page 32 of 73


Associated Items: CE 001 Flue Gas Recirculation

GP 012 CEMS and COMS - NSPS Db

SV 006 Boiler 6 210-B06

NC/CA


CD hdr MR 001, MR 002 and MR 003 are also included under EU 006.1.0

CD hdr LIMITS2.0

CD Minn. R. 7007.0800, subp. 2 Fuels allowed: natural gas with No. 2 fuel oil as backup.3.0

LIMIT 40 CFR Section 63.7575 Operating Hours: less than or equal to 48 hours/year while combustion No. 2 fueloil. This limit is required to meet the definition of a Unit Designed to Burn Gas 1subcategory in 40 CFR Section 63.7575. This limit does not apply during periods ofgas curtailment or gas supply interruptions.

This limit is effective beginning January 31, 2016.

Additional requirements for complying with 40 CFR pt. 63, subp. DDDDD are listedbelow.

4.0

LIMIT Title I Condition: Limit to avoidclassification as majormodification under 40 CFRSection 52.21; Minn. R.7007.3000

Fuel Usage: less than or equal to 1090000 gallons/year using 365-day Rolling Sumof No. 2 fuel oil. In addition: No. 2 fuel oil usage shall be less than or equal to31000 gal/day; and natural gas and No. 2 fuel oil usage combined shall be lessthan or equal to 91324 MMBtu/mo.

5.0

LIMIT Title I Condition: Limit to avoidclassification as majormodification under 40 CFRSection 52.21 and Minn. R.7007.3000; 40 CFR Section60.42b(j)(2); 40 CFR Section60.45b(j); 40 CFR Section60.47b(f); Minn. R. 7011.0565

Sulfur Content of Fuel: less than or equal to 0.5 percent by weight for No. 2 fuel oil.

This limit is less stringent than the limit required by Minn. R. 7007.0800, subp. 2.

6.0

LIMIT Minn. R. 7007.0800, subp. 2; Sulfur Content of Fuel: less than or equal to 0.05 percent by weight for No. 2 fueloil.

7.0

LIMIT 40 CFR Section 60.42b(a), (e),and (g); Minn. R. 7011.0565

Sulfur Dioxide: less than or equal to 0.20 lbs/million Btu heat input using 30-dayRolling Average . This limit applies at all times including periods of startup,shutdown, and malfunction.

The Sulfur Dioxide limit is met by complying with the fuel restrictions and fuel sulfurcontent limits.

8.0


Nitrogen Oxides: less than or equal to 0.067 lbs/million Btu heat input using24-hour Block Average for natural gas, and 0.11 lbs/million Btu heat input for No. 2fuel oil using 24-hour Block Average -- applies at all times including periods ofstartup, shutdown, or malfunction.

9.0

LIMIT 40 CFR Section 60.44b(a)(1); 40CFR Section 60.44b(h); 40 CFRSection 60.44b(i); 40 CFR Section60.46b(a); Minn. R. 7011.0565

Nitrogen Oxides: less than or equal to 0.10 lbs/million Btu heat input using 30-dayRolling Average at the low release rate (heat release rate of 70,000 Btu/hr-ft3 orless). This limit applies at all times, including periods of startup, shutdown, ormalfunction.

See MR001, MR003 and GP012 for additional monitoring requirements.

10.0


Nitrogen Oxides: less than or equal to 0.20 lbs/million Btu heat input using 30-dayRolling Average at the high release rate (heat release rate greater than 70,000Btu/hr-ft3). This limit applies at all times, including periods of startup, shutdown, ormalfunction.

11.0


Total Particulate Matter: less than or equal to 0.021 lbs/million Btu heat input using3-hour Average

12.0




12 Dec, 2014 09:18Page 33 of 73


PM < 10 micron: less than or equal to 0.021 lbs/million Btu heat input using 3-hourAverage

13.0

LIMIT 40 CFR Section 60.43b(f); 40 CFRSection 60.43b(g); 40 CFRSection 60.46b(a); Minn. R.7011.0565

Opacity: less than or equal to 20 percent opacity using 6-minute Average except forone 6-minute period per hour of not more than 27 percent opacity -- applies at alltimes, except during periods of startup, shutdown or malfunction.

See MR002 and GP012 for additional monitoring requirements.

14.0

CD hdr MONITORING AND TESTING15.0

CD Title I Condition: Monitoring forlimit to avoid classification asmajor modification under 40 CFRSection 52.21, and Minn. R.7007.3000; and 40 CFR Section60.49b(r)(1), and Minn. R.7011.0565

Fuel Oil Sulfur Content Certification: Obtain and maintain fuel receipts from the fuelsupplier which certify that the sulfur content of the fuel does not exceed 0.05% byweight. Records shall be maintained for 5 years.

Certification that the sulfur content of the fuel does not exceed 0.05% by weightmeets the fuel certification requirements of 40 CFR Section 60.41b (fuel oil meetsthe definition of distillate oil and very low sulfur oil - less then or equal to 0.5%sulfur by weight).

16.0

CD Title I Condition: Monitoring forlimit to avoid classification asmajor modification under 40 CFRSection 52.21; Minn. R.7007.3000; 40 CFR Section60.46b(e)(4); Minn. R. 7011.0565;Minn. R. 7017.2025 subp. 2

Upon request, for the NOx limit, conduct a 30-day performance test on boiler(operating at a minimum of 57 percent of maximum capacity, averaged over the30-day test period). During periods when performance tests are not requested,NOx emissions data collected pursuant to 40 CFR 60.48b(g)(1) are used tocalculate a 30-day rolling average emission rate on a daily basis and used toprepare excess emission reports, but will not be used to determine compliance withthe NOx limit. A new 30-day rolling average emission rate is calculated each steamgenerating unit operating day as the average of all of the hourly NOx emission datafor the preceding 30 steam generating unit operating days.

17.0

CD Title I Condition: Monitoring forlimit to avoid classification asmajor modification under 40 CFRSection 52.21; Minn. R.7007.3000; 40 CFR Section60.48b(b)(1), (c), (d), (e) and(g)(1); Minn. R. 7011.0565; 40CFR Section 60.13; Minn. R.7017.1010 subp. 1

Operate, maintain, and calibrate a continuous emission monitoring system (CEMS),for measuring NOx and O2 emissions, and record the output of the systemfollowing the procedures under 40 Section CFR 60.13 and 40 Section CFR pt. 60,Appendix B and Appendix F. Operate the CEMS and record data during all periodsboiler EU006 is operating except for CEMS breakdowns and repairs. Record dataduring calibration checks, and zero and span adjustments. Express the 1-houraverage NOx emission rates in lb/million Btu heat input to calculate the averageemission rates using the data points required under 40 CFR Section 60.13(h)(2).The span value for NOx is 500 ppm.

18.0

CD 40 CFR Section 60.48b(a); Minn.R. 7011.0565; and 40 CFRSection 60.13; Minn. R.7017.1010 subp. 1

Operate, maintain, and calibrate a continuous monitoring system for measuring theopacity of emissions (COMS), and record the output of the system, following theprocedures under 40 CFR Section 60.13 and 40 CFR pt. 60, Appendix B.

19.0

CD hdr RECORDKEEPING AND REPORTING20.0

CD Title I Condition: Recordkeepingfor limit to avoid classification asmajor modification under 40 CFRSection 52.21; Minn. R.7007.3000

Using purchase receipts and/or a fuel meter, record the type and amount of fuelused (and the combined heat input in MMBtu) for each calendar month by the 15thof the following month. In addition, daily record the amount of No. 2 fuel oil usedand calculate and record the 365-day rolling sum.

21.0

CD 40 CFR Section 60.49b(d); Minn.R. 7011.0565

Record and maintain records of the amounts of each fuel combusted during eachday and calculate the annual capacity factor individually for natural gas and verylow sulfur oil for the reporting period on a 12-month rolling average basis with anew annual capacity factor calculated at the end of each calendar month by the30th of the following month.

22.0




12 Dec, 2014 09:18Page 34 of 73

CD 40 CFR Section 60.49b(g); Minn.R. 7011.0565; 40 CFR Section60.13; Minn. R. 7017.1010 subp. 1

For NOx emissions, maintain records of the following for each steam generatingunit operating day:(1) Calendar date.(2) Average hourly NOx emission rates (expressed as NO2) in lb/million Btu heatinput measured.(3) 24-hour Block Average NOx emission rates in lb/million Btu heat inputcalculated at the end of each steam generating unit operating day from themeasured hourly NOx emission rates from the preceding steam generating unitoperating day.(4) Identification of the steam generating unit operating days when the calculated24-hour Block Average NOx emission rates are in excess of the NOx limit, with thereasons for excess emissions as well as a description of corrective actions taken.(5) Identification of the steam generating unit operating days for which pollutantdata have not been obtained, including reasons for not obtaining sufficient data anda description of corrective actions taken.(continued)

23.0

CD (continued)40 CFR Section 60.49b(g); Minn.R. 7011.0565; 40 CFR Section60.13; Minn. R. 7017.1010 subp. 1

(continued)(6) Identification of the times when emission data have been excluded from thecalculation of average emission rates and the reasons for excluding data.(7) Identification of "F" factor used for calculations, method of determination, andthe type of fuel combusted.(8) Identification of the times when the pollutant concentration exceeded full span ofthe CEMS.(9) Description of any modifications to the CEMS that could affect the ability of theCEMS to comply with Performance Specification 2 or 3.(10) Results of the daily CEMS drift tests and quarterly accuracy assessments asrequired under 40 CFR 60 Appendix F, Procedure 1.

24.0


Maintain records of opacity (COMS Data).25.0

CD 40 CFR Section 60.49b(v); Minn.R. 7011.0565

Option for electronic submittal of Excess Emissions/Downtime Reports (EERs):Due 30 days after end of each calendar quarter following receipt of written MPCAapproval in response to a written request to submit quarterly electronic reports forNOx and/or opacity as an alternative to written EERs on boiler (accompanied by acertification indicating whether compliance with the applicable emission standardsand minimum data requirements in 40 CFR subp. Db was achieved).

26.0


27.0



28.0



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12 Dec, 2014 09:18Page 35 of 73



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12 Dec, 2014 09:18Page 36 of 73





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12 Dec, 2014 09:18Page 37 of 73

Subject Item: EU 043 Boiler No. 7 - Boiler

Associated Items: CE 002 Flue Gas Recirculation


SV 043 Boiler 7, 210-B07 [1]

NC/CA


CD hdr MR 004, MR 005, MR 006 and MR 007 are also included under EU 043.1.0

CD hdr EMISSION AND OPERATING LIMITS2.0

CD Minn. R. 7007.0800, subp. 2 Fuels allowed: natural gas with No. 2 fuel oil as backup only.3.0

LIMIT 40 CFR Section 63.7575 Operating Hours: less than or equal to 48 hours/year while combustion No. 2 fueloil. This limit is required to meet the definition of a Unit Designed to Burn Gas 1subcategory in 40 CFR Section 63.7575. This limit does not apply during periods ofgas curtailment or gas supply interruptions.

This limit is effective beginning January 31, 2016.

Additional requirements for complying with 40 CFR pt. 63, subp. DDDDD are listedbelow.

4.0

LIMIT Title I Condition: Limit to avoidclassification as majormodification under 40 CFRSection 52.21, and Minn. R.7007.3000

Nitrogen Oxides: less than or equal to 39.0 tons/year using 365-day Rolling Sum5.0


Sulfur Dioxide: less than or equal to 38.0 tons/year using 12-month Rolling Sum6.0

LIMIT Minn. R. 7007.0800, subp. 2 Sulfur Content of Fuel: less than or equal to 0.05 percent by weight for No. 2 fueloil.

7.0

LIMIT 40 CFR Section 60.42b(a), (e),and (g); Minn. R. 7011.0565

Sulfur Dioxide: less than or equal to 0.20 lbs/million Btu heat input using 30-dayRolling Average . This limit applies at all times including periods of startup,shutdown, and malfunction.

The Sulfur Dioxide limit is met by complying with the fuel restrictions and fuel sulfurcontent limits.

8.0


PM < 10 micron: less than or equal to 13.0 tons/year using 12-month Rolling Sum9.0


Fuel Usage: less than or equal to 10 million gallons/year using 12-month RollingSum of No. 2 Fuel Oil.

10.0

LIMIT Title I Condition: Limit to avoidclassification as majormodification under 40 CFRSection 52.21 and Minn. R.7007.3000; 40 CFR 60.42b(j)(2);40 CFR Section 60.45b(j); 40 CFRSection 60.47b(f); Minn. R.7011.0565; Minn. R. 7011.0515,subp. 1

Sulfur Content of Fuel: less than or equal to 0.5 percent by weight for No. 2 fuel oil.

This limit is less stringent than the limit required by Minn. R. 7007.0800, subp. 2.

11.0


Nitrogen Oxides: less than or equal to 0.20 lbs/million Btu heat input using 30-dayRolling Average for a boiler with high heat release design (heat release rate atmaximum heat input is greater than 70,000 Btu/hr-cubic foot). This limit applies atall times including periods of startup, shutdown, or malfunction.

12.0




12 Dec, 2014 09:18Page 38 of 73

LIMIT 40 CFR Section 60.43b(f); 40 CFRSection 60.43b(g); 40 CFRSection 60.46b(a); Minn. R.7011.0565; Minn. R. 7011.0515,subp. 2

Opacity: less than or equal to 20 percent opacity using 6-minute Average except forone 6-minute period per hour of not more than 27 percent opacity -- applies at alltimes, except during periods of startup, shutdown or malfunction

13.0

CD hdr MONITORING AND TESTING14.0

CD Title I Condition: Limit to avoidclassification as majormodification under 40 CFRSection 52.21, and Minn. R.7007.3000; 40 CFR Section60.49b(r)(1); Minn. R. 7011.0565

Fuel Oil Sulfur Content Certification: Obtain and maintain fuel receipts from the fuelsupplier which certify that the sulfur content of the fuel does not exceed 0.05% byweight. Records shall be maintained for 5 years.

Certification that the sulfur content of the fuel does not exceed 0.05% by weightmeets the fuel certification requirements of 40 CFR Section 60.41b (fuel oil meetsthe definition of distillate oil and very low sulfur oil - less then or equal to 0.5%sulfur by weight).

15.0

CD Title I Condition: Limit to avoidclassification as majormodification under 40 CFRSection 52.21, and Minn. R.7007.3000; 40 CFR Section60.46b(e)(4); Minn. R. 7011.0565;Minn. R. 7017.2025 subp. 2

Upon request, for the NOx limit, conduct a 30-day performance test on boiler.During periods when performance tests are not requested, NOx emissions datacollected pursuant to 40 CFR 60.48b(g)(1) are used to calculate a 30-day rollingaverage emission rate on a daily basis and used to prepare excess emissionreports, but will not be used to determine compliance with the NOx limit. A new30-day rolling average emission rate is calculated each steam generating unitoperating day as the average of all of the hourly NOx emission data for thepreceding 30 steam generating unit operating days.

16.0

CD Title I Condition: Limit to avoidclassification as majormodification under 40 CFRSection 52.21, and Minn. R.7007.3000; 40 CFR Section60.48b(b)(1), (c), (d), (e) and(g)(1); Minn. R. 7011.0565; 40CFR Section 60.13; Minn. R.7017.1010 subp. 1

Operate, maintain, and calibrate a continuous emission monitoring system (CEMS),and record the output of the system, for measuring NOx emissions, following theprocedures under 40 CFR 60.13 and 40 CFR pt. 60, Appendix B and Appendix F.Operate the CEMS and record data during all periods boiler EU 043 is operatingexcept for CEMS breakdowns and repairs. Record data during calibration checks,and zero and span adjustments. Express the 1-hour average NOx emission ratesin lb/million Btu heat input to calculate the average emission rates using the datapoints required under 40 CFR 60.13(h).

17.0

CD 40 CFR Section 60.48b(a); Minn.R. 7011.0565; 40 CFR Section60.13; Minn. R. 7017.1010 subp.1; 40 CFR Section 60.43b(g)

Operate, maintain, and calibrate a continuous monitoring system for measuring theopacity of emissions (COMS), and record the output of the system, following theprocedures under 40 CFR 60.13 and 40 CFR pt. 60, Appendix B.

Opacity Standards apply at all times, except during periods of startup, shutdown ormalfunction.

18.0

CD hdr RECORDKEEPING AND REPORTING19.0

CD Title I Condition: Limit to avoidclassification as majormodification under 40 CFRSection 52.21, and Minn. R.7007.3000; 40 CFR Part 60, App.A, Meth. 19; Minn. R. 7007.0800,subp. 5

Recordkeeping of Amount of Fuel Used and NOx Concentration:

To show compliance with the NOx emissions limit based on a 365-day rolling sum,the Permittee shall1) record the type and amount of fuel used at this emission unit;2) record NOx concentration of each fuel on a daily basis;and3) calculate and record the 365-day rolling sum of NOx emissions, using 40 CFRAppendix A, Method 19 (Determination of Nitrogen Oxides Emission Rates).

The calculation methodology shown in 40 CFR Appendix A, Method 19 may beused for computing CO emissions.

20.0

CD Title I Condition: Limit to avoidclassification as majormodification under 40 CFRSection 52.21, and Minn. R.7007.3000; Minn. R. 7007.0800,subp. 5

Recordkeeping of Amount and Type of Fuel Used:

To show compliance with the PM, PM10, and SO2 emissions limit based on a365-day rolling sum, the Permittee shall1) record the type and amount of fuel used at this emission unit;and2) calculate and record the 365-day rolling sum of PM, PM10, and SO2 emissions,using the EPA AP-42 emission factors, or other factors approved by theCommissioner.

21.0

CD Title I Condition: Limit to avoidclassification as majormodification under 40 CFRSection 52.21, and Minn. R.7007.3000

Using purchase receipts and/or a fuel meter, record the type and amount of fuelused (and the combined heat input in MMBtu) for each calendar month by the 15thof the following month. In addition, daily record the amount of No. 2 fuel oil usedand calculate and record the 365-day rolling sum.

22.0




12 Dec, 2014 09:18Page 39 of 73

CD 40 CFR Section 60.49b(d); Minn.R. 7011.0565

Record and maintain records of the amounts of each fuel combusted during eachday and calculate the annual capacity factor individually for natural gas and verylow sulfur oil for the reporting period on a 12-month rolling average basis with anew annual capacity factor calculated at the end of each calendar month by the30th of the following month.

23.0

CD 40 CFR Section 60.49b(g); Minn.R. 7011.0565; 40 CFR Section60.13; Minn. R. 7017.1010 subp. 1

For NOx emissions, maintain records of the following for each steam generatingunit operating day:(1) Calendar date.(2) Average hourly NOx emission rates (expressed as NO2) in lb/million Btu heatinput measured.(3) The 30-day average NOx emission rates in lb/million Btu heat input calculatedat the end of each steam generating unit operating day from the measured hourlyNOx emission rates from the preceding 30 steam generating unit operating days.(4) Identification of the steam generating unit operating days when the calculated30-day average NOx emission rates are in excess of the NOx limit under 40 CFRSection 60.44b, with the reasons for excess emissions as well as a description ofcorrective actions taken.(5) Identification of the steam generating unit operating days for which pollutantdata have not been obtained, including reasons for not obtaining sufficient data anda description of corrective actions taken.(continued)

24.0

CD (continued)40 CFR Section 60.49b(g); Minn.R. 7011.0565; 40 CFR Section60.13; Minn. R. 7017.1010 subp. 1

(continued)(6) Identification of the times when emission data have been excluded from thecalculation of average emission rates and the reasons for excluding data.(7) Identification of "F" factor used for calculations, method of determination, andthe type of fuel combusted.(8) Identification of the times when the pollutant concentration exceeded full span ofthe CEMS.(9) Description of any modifications to the CEMS that could affect the ability of theCEMS to comply with Performance Specification 2 or 3.(10) Results of the daily CEMS drift tests and quarterly accuracy assessments asrequired under 40 CFR 60 Appendix F, Procedure 1.

25.0


Maintain records of opacity (COMS Data).26.0

CD 40 CFR Section 60.49b(v); Minn.R. 7011.0565

Option for electronic submittal of Excess Emissions/Downtime Reports (EERs):Due 30 days after end of each calendar quarter following receipt of written MPCAapproval in response to a written request to submit quarterly electronic reports forNOx and/or opacity as an alternative to written EERs on boiler (accompanied by acertification indicating whether compliance with the applicable emission standardsand minimum data requirements in 40 CFR subp. Db was achieved during thereporting period). Before submitting reports in the electronic format, the Permitteeshall coordinate with the permitting authority to obtain their agreement to submitreports in this alternative format.

27.0


28.0



29.0



30.0




31.0




12 Dec, 2014 09:18Page 40 of 73



32.0



33.0




34.0



Previously, 3M was required to submit semi-annual compliance reports for EU043under the old Boiler NESHAP. The old boiler NESHAP has been vacated andreplaced. As such, 3M is not required to submit semi-annual compliance reportsuntil the new compliance date: January 31, 2016.

35.0





36.0


37.0




12 Dec, 2014 09:18Page 41 of 73





38.0





39.0




12 Dec, 2014 09:18Page 42 of 73

Subject Item: EU 044 NG Boiler 278 - Boiler

Associated Items: GP 010 Bldg 278 NG Boilers

SV 044 NG Boiler 278

NC/CA


LIMIT Minn. R. 7011.0515, subp. 1 Total Particulate Matter: less than or equal to 0.4 lbs/million Btu heat input . ThePotential To Emit is 0.0072 lbs/million BTU heat input per equipment design.

1.0


2.0

CD Minn. R. 7007.0800, subp. 2 Fuels Allowed: Natural Gas only by design.3.0


4.0



5.0


The Permittee shall complete a tune-up of EU044 every 5 years as specified in 40CFR Section 63.7540. Boilers and process heaters in the units designed to burngas 1 fuels subcategory are not subject to the emission limits in Tables 1 and 2 or11 through 13, or the operating limits in Table 4 of 40 CFR pt. 63, subp. DDDDD.

6.0




7.0



8.0



9.0




10.0




12 Dec, 2014 09:18Page 43 of 73



11.0



The Permittee shall submit the Compliance Report according to 40 CFR Section63.7550(h) by the date in 40 CFR pt. 63, subp. DDDDD, Table 9 and according tothe requirements in 40 CFR Section 63.7550(b)(1) through (4). The Permittee maysubmit only a 5-year compliance report instead of a semi-annual compliance report.


12.0


13.0





14.0





15.0




12 Dec, 2014 09:18Page 44 of 73




NC/CA



1.0


2.0



4.0



5.0



6.0




7.0



8.0



9.0




10.0




12 Dec, 2014 09:18Page 45 of 73



11.0





12.0


13.0





14.0





15.0




12 Dec, 2014 09:18Page 46 of 73




NC/CA



1.0


2.0



4.0



5.0



6.0




7.0



8.0



9.0




10.0




12 Dec, 2014 09:18Page 47 of 73



11.0





12.0


13.0





14.0





15.0




12 Dec, 2014 09:18Page 48 of 73

Subject Item: EU 048 Emergency Generator #1 Bldg 220 - Reciprocating IC Engine

Associated Items: GP 005 New, <= 500 Hp, Emergency Engines

GP 008 Diesel Generators < 600 Hp

GP 011 Best Management Practices for Emergency Engines

SV 048 Diesel Generator # 1 Bldg 220

NC/CA


CD hdr EMISSION LIMITS - NSPS SUBP. IIII1.0

LIMIT 40 CFR Section 60.4205(b); 40CFR Section 60.4202(a)(2); 40CFR Section 89.112; Minn. R.7011.2305

Total Particulate Matter: less than or equal to 0.20 grams/kilowatt-hour .2.0


NMHC+NOx: less than or equal to 4.0 grams/kilowatt-hour3.0


Carbon Monoxide: less than or equal to 3.50 grams/kilowatt-hour4.0

CD 40 CFR Section 60.4205(b); 40CFR Section 60.4202(a)(2); 40CFR Section 89.113; Minn. R.7011.2305

The Permittee shall operate the EU048 such that it meets the following smokeemission standards:

Smoke emission standard:The exhaust opacity shall not exceed:i. 20 percent during the acceleration mode;ii. 15 percent during the lugging mode;iii. 50 percent during the peaks in either the acceleration or lugging modes.

5.0

CD 40 CFR Section 60.4206; Minn. R.7011.2305

The Permittee shall operate and maintain EU048 so that it achieves the emissionsstandards as required in 60 CFR Section 60.4205 over the entire life of the engine.

6.0

CD hdr OPERATING REQUIREMENTS - NSPS SUBP. IIII7.0


Fuel Use: only diesel fuel that meets the requirements of 40 CFR Section 80.510(b)for nonroad diesel fuel:1. Maximum sulfur content of 15 ppm2. Minimum centane index of 40; or maximum aromatic content of 35 volumepercent

8.0

CD 40 CFR 60.4209(a); Minn. R.7011.2305

The Permittee shall install a non-resettable hour meter prior to startup of theengine. The non-resettable hour meter shall be maintained for the life of the engine.

9.0


The Permittee shall:1. Operate and maintain the stationary CI internal combustion engine and controldevice according to the manufacturer's emission-related written instructions;2. Change only those emission-related settings that are permitted by themanufacturer; and3. Meet the requirements of 40 CFR pts. 89, 94 and/or 1068, as they apply.

10.0


The Permittee shall comply with the emission standards specified in 40 CFRSection 60.4205(b) by purchasing an engine certified to the emission standards in40 CFR Section 60.4205, for the same model year and maximum engine power.The engine shall be installed and configured according to the manufacturer'semission-related specifications.

11.0


The Permittee shall operate the EU48 according to the requirements in 40 CFRSection 60.4211(f)(1) through (f)(2)(i). In order for the engine to be considered anemergency stationary ICE under this 40 CFR pt. 60, subp. IIII, any operation otherthan emergency operation and maintenance and testing as described in 40 CFRSection 60.4211(f)(1) through (f)(2)(i), is prohibited. If the Permittee does notoperate the engine according to the requirements in 40 CFR Section 60.4211(f)(1)through (f)(2)(i), the engine will not be considered an emergency engine under 40CFR pt. 60, subp. IIII, the Permittee will be in violation of this permit, and enginemust meet all requirements for non-emergency engines.

12.0




12 Dec, 2014 09:18Page 49 of 73


There is no time limit on the use of emergency stationary ICE in emergencysituations.

13.0

LIMIT 40 CFR Section 60.4211(f)(2); 40CFR Section 63.6590(b)(1); Minn.R. 7011.2305; Minn. R. 7011.8150

Operating Hours: less than or equal to 100 hours/year for the purposes specified inparagraph (i), based on a calendar year. Any operation for non-emergencysituations as allowed by 40 CFR Section 60.4211(f)(2)(i) counts as part of the 100hours per calendar year allowed by 40 CFR Section 60.4211(f)(2). The Permitteeshall not operate or enter into a contract to operate EU048 for the purposes ofdemand response or to avoid voltage deviation.

(i) EU051 may be operated for maintenance checks and readiness testing,provided that the tests are recommended by federal, state or local government, themanufacturer, the vendor, the regional transmission organization or equivalentbalancing authority and transmission operator, or the insurance companyassociated with the engine.

14.0

CD hdr RECORDKEEPING - NSPS SUBP. IIII15.0


Recordkeeping: The Permittee shall maintain records of the operation of the enginein emergency service that are recorded through the non-resettable hour meter. Therecord must include the time of operation and the reason the generator was inoperation during that time.

16.0

CD hdr GENERAL REQUIREMENTS - NSPS SUBP. A17.0


Circumvention: Do not build, erect, install or use any article, machine, equipment orprocess, the use of which conceals an emission which would otherwise constitute aviolation of an applicable standard. Such concealment includes, but is not limitedto, the use of gaseous diluents to achieve compliance with an opacity standard orwith a standard which is based on the concentration of a pollutant in the gasesdischarged to the atmosphere.

18.0




12 Dec, 2014 09:18Page 50 of 73

Subject Item: EU 049 Emergency Generator #2 Bldg 220 - Reciprocating IC Engine


GP 008 Diesel Generators < 600 Hp


SV 049 Diesel Generator # 2 Bldg 220

NC/CA




Total Particulate Matter: less than or equal to 0.20 grams/kilowatt-hour2.0








5.0



6.0




8.0

CD 40 CFR 60.4209(a); Minn. R.7011.2305


9.0



10.0



11.0



12.0




12 Dec, 2014 09:18Page 51 of 73



13.0




14.0




16.0




18.0




12 Dec, 2014 09:18Page 52 of 73

Subject Item: EU 050 Diesel Fire Pump Bldg 217 - Reciprocating IC Engine



SV 050 Diesel Fire Pump Bldg 217

NC/CA



LIMIT 40 CFR Section 60.4205(c); 40CFR pt. 60, subp. IIII, Table 4;Minn. R. 7011.2305


LIMIT 40 CFR Section 60.4205(c); 40CFR pt. 60, subp. IIII, Table 4;Minn. R. 7011.2305




4.0




6.0

CD 40 CFR 60.4209(a); Minn. R.7011.2305


7.0



8.0



9.0


The Permittee shall operate the EU050 according to the requirements in 40 CFRSection 60.4211(f)(1) through (f)(2)(i). In order for the engine to be considered anemergency stationary ICE under this 40 CFR pt. 60, subp. IIII, any operation otherthan emergency operation and maintenance and testing as described in 40 CFRSection 60.4211(f)(1) through (f)(2)(i), is prohibited. If the Permittee does notoperate the engine according to the requirements in 40 CFR Section 60.4211(f)(1)through (f)(2)(i), the engine will not be considered an emergency engine under 40CFR pt. 60, subp. IIII and must meet all requirements for non-emergency engines.

10.0



11.0




12.0





12 Dec, 2014 09:18Page 53 of 73



14.0




16.0




12 Dec, 2014 09:18Page 54 of 73

Subject Item: EU 051 Emergency Generator Bldg 217 - Reciprocating IC Engine

Associated Items: GP 004 New, CI > 500 Hp, Emergency Engines

GP 009 Diesel Generators > 600 Hp


SV 051 Emergency Generator Bldg 217

NC/CA


CD 40 CFR Section 63.6590(b)(1);Minn. R. 7011.2305

The Permittee shall operate EU051 such that it meets the requirements of aStationary RICE subject to limited requirements (see 40 CFR Section63.6590(b)(1)). If the Permittee does not operate EU051 according to therequirements of 40 CFR Section 63.6590(b)(1), EU051 will not be considered anengine subject to limited requirements and must meet all applicable requirementsof 40 CFR pt. 63, subps. A and ZZZZ.

1.0











6.0



7.0




9.0

CD 40 CFR 60.4209(a); Minn. R.7011.2305


10.0



11.0



12.0




12 Dec, 2014 09:18Page 55 of 73



13.0



14.0




15.0




17.0




19.0




12 Dec, 2014 09:18Page 56 of 73



GP 007 Natural Gas Emergency Generators



NC/CA


CD 40 CFR Section 63.6590(c)(6); 40CFR Section 60.4230(a)(4)(iv);Minn. R. 7011.2300; Minn. R.7011.2310

Under 40 CFR Section 63.6590(c)(6), compliance with the requirements of 40 CFRpt. 63, subp. ZZZZ is met by meeting the requirements of 40 CFR pt. 60, subp.JJJJ.

Under 40 CFR Section 60.4230(a)(4)(iv), the requirements of 40 CFR pt. 60, subp.JJJJ apply to emergency engines with a maximum engine power greater than19kW that were manufactured on or after January 1, 2009.

This engine was manufactured before January 1, 2009; therefore no requirementsfrom 40 CFR pt. 60, subp. JJJJ apply.

1.0

CD Minn. R. 7005.0100, subp. 35a Fuel Type: Natural gas only be design.2.0

CD Minn. R. 7007.0800, subp. 2 The Permittee shall install a non-resettable hour meter prior to startup of theengine. The non-resettable hour meter shall be maintained for the life of the engine.

3.0


Recordkeeping: The Permittee shall keep records of the hours of operation of theengine that is recorded through the non-resettable hour meter.

4.0




12 Dec, 2014 09:18Page 57 of 73



GP 007 Natural Gas Emergency Generators



NC/CA


CD hdr EMISSION LIMITS - NSPS SUBP. JJJJ1.0

LIMIT 40 CFR Section 60.4233(e); 40CFR pt. 60, subp. JJJJ, Table 1;Minn. R. 7011.2310

Nitrogen Oxides: less than or equal to 2.0 grams/kilowatt-hour or less than or equalto 160 ppm, volumetric, dry at 15% oxygen.

2.0


Carbon Monoxide: less than or equal to 4.0 grams/kilowatt-hour or less than orequal to 540 ppm, volumetric, dry at 15% oxygen.

3.0


Volatile Organic Compounds: less than or equal to 1.0 grams/kilowatt-hour or lessthan or equal to 86 ppm, volumetric, dry at 15% oxygen. For the purposes ofdetermining compliance with this limit, when calculating emissions of volatileorganic compounds, emissions of formaldehyde should not be included.

4.0



5.0

CD hdr OPERATING REQUIREMENTS - NSPS SUBP. JJJJ6.0



7.0


The Permittee shall demonstrate compliance with the emissions limits in this permitaccording to one of the methods specified in paragraphs 1 and 2:1. Purchasing an engine certified according to the procedures specified in 40 CFRpt. 60, subp. JJJJ, for the same model year and demonstrating complianceaccording to one of the methods specified in 40 CFR Section 60.4243(a).

2. Purchasing a non-certified engine and demonstrating compliance with theemission standards specified in 40 CFR Section 60.4233(e) and according to therequirements specified in 40 CFR Section 60.4244, as applicable, and according toparagraph i:

i. The Permittee shall keep a maintenance plan and records of conductedmaintenance and shall, to the extent practicable, maintain and operate the enginein a manner consistent with good air pollution control practice for minimizingemissions. The Permittee shall conduct an initial performance test to demonstratecompliance.

8.0


The Permittee shall operate EU053 according to the requirements in 40 CFRSection 60.4243(d)(1) through (d)(2)(i). In order for the engine to be considered anemergency stationary ICE under 40 CFR pt. 60, subp. JJJJ, any operation otherthan emergency operation and maintenance and testing as described in 40 CFRSection 60.4243(d)(1) through (d)(2)(i), is prohibited. If the Permittee does notoperate the engine according to the requirements in 40 CFR Section 60.4243(d)(1)through (d)(2)(i), the engine will not be considered an emergency engine under 40CFR pt. 60, subp. JJJJ, the Permittee will be in violation of this permit, and enginemust meet all requirements for non-emergency engines.

9.0

CD 40 CFR Section 60.4243(d)(1);Minn. R. 7011.2310


10.0

LIMIT 40 CFR Section 60.4243(d)(2);Minn. R. 7011.2310

Operating Hours: less than or equal to 100 hours/year for the purposes specified inparagraph (i), based on a calendar year. Any operation for non-emergencysituations as allowed by 40 CFR Section 60.4243(d)(2)(i) counts as part of the 100hours per calendar year allowed by 40 CFR Section 60.4243(d)(2). The Permitteeshall not operate or enter into a contract to operate EU053 for the purposes ofdemand response or to avoid a voltage deviation.(i) EU053 may be operated for maintenance checks and readiness testing,provided that the tests are recommended by federal, state or local government, themanufacturer, the vendor, the regional transmission organization or equivalentbalancing authority and transmission operator, or the insurance companyassociated with the engine.

11.0




12 Dec, 2014 09:18Page 58 of 73


The Permittee may operate EU053 using propane for a maximum of 100 hours peryear as an alternative fuel solely during emergency operations. The Permittee shallkeep records of such use. If propane is used for more than 100 hours per year inan engine that is not certified to the emission standards when using propane, thePermittee shall conduct a performance test to demonstrate compliance with theemission standards of 40 CFR Section 60.4233.

12.0

CD hdr RECORDKEEPING - NSPS SUBP. JJJJ13.0


Recordkeeping: The Permittee shall maintain records of:1. All notifications submitted to comply with 40 CFR pt. 60, subp. JJJJ and alldocumentation supporting any notification.2. Maintenance conducted on the engine.3. If the stationary SI ICE is a certified engine, documentation from themanufacturer that the engine is certified to meet the emission standards andinformation as required in 40 CFR parts 90, 148, 1054, and 1060, as applicable.4. If the stationary SI ICE is not a certified engine or is a certified engine operatingin a non-certified manner and subject to 40 CFR Section 60.4243(a)(2),documentation that the engine meets the emission standards.

14.0


Recordkeeping: The Permittee shall keep records of the hours of operation of theengine that is recorded through the non-resettable hour meter.

15.0




17.0




12 Dec, 2014 09:18Page 59 of 73

Subject Item: EU 054 Emergency Generator Bldg 217 EU012 Replacement Generator - Reciprocating IC Engine

Associated Items: GP 004 New, CI > 500 Hp, Emergency Engines



SV 012 NG Generator 210-296269

NC/CA



The Permittee shall operate EU054 such that it meets the requirements of aStationary RICE subject to limited requirements (see 40 CFR Section63.6590(b)(1)). If the Permittee does not operate EU054 according to therequirements of 40 CFR Section 63.6590(b)(1), EU054 will not be considered anengine subject to limited requirements and must meet all applicable requirementsof 40 CFR pt. 63, subps. A and ZZZZ.

1.0











6.0



7.0




9.0

CD 40 CFR 60.4209(a); Minn. R.7011.2305


10.0



11.0



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12 Dec, 2014 09:18Page 60 of 73



13.0



14.0




15.0




17.0




19.0




12 Dec, 2014 09:18Page 61 of 73

Subject Item: EU 055 Diesel Emergency Generator Bldg 280 - Reciprocating IC Engine

Associated Items: CE 003 Diesel Particulate Filter

GP 004 New, CI > 500 Hp, Emergency Engines




NC/CA



The Permittee shall operate EU055 such that it meets the requirements of aStationary RICE subject to limited requirements (see 40 CFR Section63.6590(b)(1)). If the Permittee does not operate EU055 according to therequirements of 40 CFR Section 63.6590(b)(1), EU055 will not be consideredengines subject to limited requirements and must meet all applicable requirementsof 40 CFR pt. 63, subps. A and ZZZZ.

1.0











6.0



7.0




9.0



10.0


The Permittee shall equip EU055 with a diesel particulate filter. The dieselparticulate filter shall be installed with a backpressure monitor that notifies thePermittee when the high backpressure limit of the engine is approached.

11.0



12.0



13.0




12 Dec, 2014 09:18Page 62 of 73


The Permittee shall operate EU055 according to the requirements in 40 CFRSection 60.4211(f)(1) through (f)(2)(i). In order for the engine to be considered anemergency stationary ICE under this 40 CFR pt. 60, subp. IIII, any operation otherthan emergency operation and maintenance and testing as described in 40 CFRSection 60.4211(f)(1) through (f)(2)(i), is prohibited. If the Permittee does notoperate the engine according to the requirements in 40 CFR Section 60.4211(f)(1)through (f)(2)(i), the engine will not be considered an emergency engine under 40CFR pt. 60, subp. IIII, the Permittee will be in violation of this permit, and enginemust meet all requirements for non-emergency engines.

14.0



15.0




16.0




18.0




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12 Dec, 2014 09:18Page 63 of 73

Subject Item: CE 003 Diesel Particulate Filter

Associated Items: EU 055 Diesel Emergency Generator Bldg 280 - Reciprocating IC Engine

NC/CA


LIMIT Minn. R. 7007.0800, subp. 2 Total Particulate Matter: greater than or equal to 85.0 percent control efficiency1.0

LIMIT Minn. R. 7007.0800, subp. 2 PM < 10 micron: greater than or equal to 85.0 percent control efficiency2.0

LIMIT Minn. R. 7007.0800, subp. 2 PM < 2.5 micron: greater than or equal to 85.0 percent control efficiency3.0

LIMIT Minn. R. 7007.0800, subp. 2 Carbon Monoxide: greater than or equal to 90.0 percent control efficiency4.0


The Permittee shall check the back pressure alarm on the diesel particulate filteronce during each period of operation. If the monitor signals that the high backpressure limit of the engine is approached, the Permittee shall take correctiveaction.

5.0


Corrective Actions: If the diesel particulate filter or any of the components are foundduring the inspections in need of repair, the Permittee shall take corrective actionas soon as possible. Corrective actions shall include completion of necessaryrepairsidentified during the inspection, as applicable. Corrective actions include, but arenot limited to, those outlined in the O & M Plan for the diesel particulate filter. ThePermittee shall keep a record of the type and date of any corrective action taken foreach filter.

6.0




12 Dec, 2014 09:18Page 64 of 73

Subject Item: TK 002 Gasoline (Unleaded)

NC/CA


CD Minn. R. 7011.1505, subp. 3(B) Operational Requirement: The Permittee shall equip the storage vessel (tank) witha permanent submerged fill pipe or comply with the following requirements:

(1) If the true vapor pressure of the petroleum liquid, as stored, is equal to orgreater than 78 mm Hg (1.5 psia) but not greater than 570 mm Hg (11.1 psia), thestorage vessel should be equipped with a floating roof, a vapor recovery system, ortheir equivalents.

(2) If the true vapor pressure of the petroleum liquid, as stored, is greater than 570mm Hg (11.1 psia), the storage vessel should be equipped with a vapor recoverysystem, or its equivalents.

1.0




12 Dec, 2014 09:18Page 65 of 73

Subject Item: TK 003 Gasoline (Unleaded)

NC/CA


CD Minn. R. 7011.1505, subp. 3(B) Operational Requirement: The Permittee shall equip the storage vessel (tank) witha permanent submerged fill pipe or comply with the following requirements:

(1) If the true vapor pressure of the petroleum liquid, as stored, is equal to orgreater than 78 mm Hg (1.5 psia) but not greater than 570 mm Hg (11.1 psia), thestorage vessel should be equipped with a floating roof, a vapor recovery system, ortheir equivalents.

(2) If the true vapor pressure of the petroleum liquid, as stored, is greater than 570mm Hg (11.1 psia), the storage vessel should be equipped with a vapor recoverysystem, or its equivalents.

1.0




12 Dec, 2014 09:18Page 66 of 73

Subject Item: TK 007 No. 2 Fuel Oil (very low sulfur)

NC/CA


CD Minn. R. 7011.1505, subp. 3(C) For storage vessels with a storage capacity of greater than 40,000 gallons thePermittee shall comply with the following requirements:

(1) If the true vapor pressure of the petroleum liquid, as stored, is equal to or

greater than 1.5 psia but not greater than 11.1 psia, the storage vessel shall be

equipped with a floating roof, a vapor recovery system or their equivalents.

(2) If the true vapor pressure of the petroleum liquid, as stored, is greater than 11.1

psia, the storage vessel shall be equipped with a vapor recovery system or its

equivalent.

1.0




12 Dec, 2014 09:18Page 67 of 73

Subject Item: MR 001 NOx

Associated Items: CM 001 NOx


SV 006 Boiler 6 210-B06

NC/CA


S/A 40 CFR pt. 60, Appendix F,section 5.1.2; Minn. R. 7017.1170,subp. 4

CEMS Cylinder Gas Audit (CGA): due before end of each calendar half-yearfollowing CEM Certification Test for NOx CEMS. Conduct the CGA on eachconcentration and diluent monitor. The CGA shall be conducted on each monitorrange. Conduct the CGA at least 3 months apart and not greater than 8 monthsapart. If a RATA is performed during the calendar half-year the CGA is notrequired. Follow the procedures in 40 CFR pt. 60, Appendix F, section 5.1.2.

1.0

CD 40 CFR pt. 60, Appendix F,Section 5.1.1; Minn. R.7017.1170, subp. 5

CEMS Relative Accuracy Test Audit (RATA): due before end of every one of fourcalendar quarters following Permit Issuance. RATA's shall be conducted at leastthree months apart and according to the procedures in 40 CFR pt. 60, appendix F,section 5.1.1.

2.0

S/A Minn. R. 7017.1180, subp.1 Cylinder Gas Audit (CGA) Results Summary: due 30 days after end of eachcalendar half-year following end of the calendar quarter in which the Audit wasperformed for NOx CEMS.

3.0

S/A Minn. R. 7017.1180, subp. 2 Relative Accuracy Test Audit (RATA) Notification: due 30 days before CEMSRelative Accuracy Test Audit (RATA)

4.0

S/A Minn. R. 7017.1180, subp. 3 Relative Accuracy Test Audit (RATA) Results Summary: due 30 days after CEMSRelative Accuracy Test Audit (RATA)

5.0

CD 40 CFR Section 60.13(d)(1); 40CFR pt. 60, Appendix F, section4.1; Minn. R. 7017.1170, subp. 3;Minn. R. 7017.1010

NOx CEMS Daily Calibration Drift (CD) Test: The Permittee shall conduct dailycalibration drift assessments and make adjustments as needed according to theprocedure listed in Minn. R. 7017.1170, subp. 3 (A) and (B), and 40 CFR Section60.13(d)(1), for each pollutant concentration and diluent monitor. The calibrationdrift assessment shall be conducted on each monitor range. The Permittee shallcheck the zero (or low level value between 0 and 20 percent of span value) andspan (50 to 100 percent of span value) calibration drifts at least once eachoperating day. The zero and span must, at a minimum, be adjusted whenevereither the 24-hour zero drift or the 24-hour span drift exceeds two times the limit ofthe applicable performance specification in 40 CFR pt. 60, appendix B. The systemshall record and quantify the excess zero and span drift whenever specified.

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12 Dec, 2014 09:18Page 68 of 73

Subject Item: MR 002 Opacity

Associated Items: CM 002 Opacity


SV 006 Boiler 6 210-B06

NC/CA


S/A 40 CFR Section 60.7(a)(7); Minn.R. 7019.0100

Notification of compliance status: due 30 days before Performance Test required by40 CFR Section 60.8 if COMS data results will be used in lieu of 40 CFR, AppendixA, Method 9 observation data to determine compliance with the opacity standard asallowed by 40 CFR Section 60.11(e)(5).

1.0

CD 40 CFR Section 60.13(c)(1) & (2);Minn. R. 7017.1010

NSPS COMS Performance Evaluation Report: Due 10 days before theperformance test required under 40 CFR Section 60.8 and as described in Section60.11(e)(5) if the owner or operator of an affected facility elects to submit COMSdata In lieu of the performance test to demonstrate compliance with the opacitystandard. If instead the performance evalution is completed during the performancetest or within 30 days thereafter as allowed by Section 60.13(c), the report is duewithin 60 days of completion.

2.0

CD Minn. R. 7017.1180, subp. 2 COMS Calibration Error Audit Notification: due 30 days before the COMSCalibration Error Audit.

3.0

S/A Minn. R. 7017.1210, subp. 3 COMS Calibration Error Audit: due before end of each calendar half-year followingCOMS Calibration Error Audit. Audits are to be at least three months apart but nomore than eight months apart except that a calibration error audit need not beconducted during any semiannual period in which the emission unit operated lessthan 24 hours. The calibration error audit shall be conducted according to theprocedures in 40 CFR pt. 60, Appendix B, PS 1, section 7.1.4.

Filter values used shall correspond to approximately 11%, 20% and 37% opacity.

4.0

S/A Minn. R. 7017.1220 COMS Calibration Error Audit Results Summary: due 30 days after end of eachcalendar quarter following COMS Calibration Error Audit

5.0


COMS Daily Calibration Drift (CD) Test: The Permittee shall conduct dailycalibration drift assessments and make adjustments as needed according to theprocedure listed in 40 CFR Section 60.13(d)(1), for each opacity monitor. ThePermittee shall check the zero and upscale (span) calibration drifts at least oncedaily. The acceptable range of zero and upscale calibration materials is defined inthe applicable version of 40 CFR pt. 60, appendix B, PS-1. The optical surfaces,exposed to the effluent gases, shall be cleaned before performing the zero andupscale drift adjustments, except for systems using automatic zero adjustments.The optical surfaces shall be cleaned when the cumulative automatic zerocompensation exceeds 4 percent opacity.

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12 Dec, 2014 09:18Page 69 of 73

Subject Item: MR 003 Diluent O2

Associated Items: CM 003 Diluent O2


SV 006 Boiler 6 210-B06

NC/CA



CEMS Cylinder Gas Audit (CGA): due before end of each calendar half-yearfollowing CEM Certification Test for O2 CEMS. Conduct the CGA on eachconcentration and diluent monitor. The CGA shall be conducted on each monitorrange. Conduct the CGA at least 3 months apart and not greater than 8 monthsapart. If a RATA is performed during the calendar half-year the CGA is notrequired. Follow the procedures in 40 CFR pt. 60, Appendix F, section 5.1.2.

1.0



2.0

S/A Minn. R. 7017.1180, subp.1 Cylinder Gas Audit (CGA) Results Summary: due 30 days after end of eachcalendar half-year following end of the calendar quarter in which the Audit wasperformed for O2 CEMS.

3.0


4.0


5.0


O2 CEMS Daily Calibration Drift (CD) Test: The Permittee shall conduct dailycalibration drift assessments and make adjustments as needed according to theprocedure listed in Minn. R. 7017.1170, subp. 3 (A) and (B), and 40 CFR Section60.13(d)(1), for each pollutant concentration and diluent monitor. The calibrationdrift assessment shall be conducted on each monitor range. The Permittee shallcheck the zero (or low level value between 0 and 20 percent of span value) andspan (50 to 100 percent of span value) calibration drifts at least once eachoperating day. The zero and span must, at a minimum, be adjusted whenevereither the 24-hour zero drift or the 24-hour span drift exceeds two times the limit ofthe applicable performance specification in 40 CFR pt. 60, appendix B. The systemshall record and quantify the excess zero and span drift whenever specified.

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12 Dec, 2014 09:18Page 70 of 73

Subject Item: MR 004 NOx

Associated Items: GP 012 CEMS and COMS - NSPS Db

SV 043 Boiler 7, 210-B07 [1]

NC/CA



CEMS Cylinder Gas Audit (CGA): due before end of each calendar half-yearfollowing CEM Certification Test for NOx CEMS. Conduct the CGA on eachconcentration and diluent monitor. The CGA shall be conducted on each monitorrange. Conduct the CGA at least 3 months apart and not greater than 8 monthsapart. If a RATA is performed during the calendar half-year the CGA is notrequired. Follow the procedures in 40 CFR pt. 60, Appendix F, section 5.1.2.

1.0



2.0

S/A Minn. R. 7017.1180, subp.1 Cylinder Gas Audit (CGA) Results Summary: due 30 days after end of eachcalendar half-year following end of the calendar quarter in which the Audit wasperformed for NOx CEMS.

3.0


4.0


5.0


NOx CEMS Daily Calibration Drift (CD) Test: The Permittee shall conduct dailycalibration drift assessments and make adjustments as needed according to theprocedure listed in Minn. R. 7017.1170, subp. 3 (A) and (B), and 40 CFR Section60.13(d)(1), for each pollutant concentration and diluent monitor. The calibrationdrift assessment shall be conducted on each monitor range. The Permittee shallcheck the zero (or low level value between 0 and 20 percent of span value) andspan (50 to 100 percent of span value) calibration drifts at least once eachoperating day. The zero and span must, at a minimum, be adjusted whenevereither the 24-hour zero drift or the 24-hour span drift exceeds two times the limit ofthe applicable performance specification in 40 CFR pt. 60, appendix B. The systemshall record and quantify the excess zero and span drift whenever specified.

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12 Dec, 2014 09:18Page 71 of 73

Subject Item: MR 005 CO


SV 043 Boiler 7, 210-B07 [1]

NC/CA



CEMS Cylinder Gas Audit (CGA): due before end of each calendar half-yearfollowing CEM Certification Test for CO CEMS. Conduct the CGA on eachconcentration and diluent monitor. The CGA shall be conducted on each monitorrange. Conduct the CGA at least 3 months apart and not greater than 8 monthsapart. If a RATA is performed during the calendar half-year the CGA is notrequired. Follow the procedures in 40 CFR pt. 60, Appendix F, section 5.1.2.

1.0



2.0

S/A Minn. R. 7017.1180, subp.1 Cylinder Gas Audit (CGA) Results Summary: due 30 days after end of eachcalendar half-year following end of the calendar quarter in which the Audit wasperformed for CO CEMS.

3.0


4.0


5.0


CO CEMS Daily Calibration Drift (CD) Test: The Permittee shall conduct dailycalibration drift assessments and make adjustments as needed according to theprocedure listed in Minn. R. 7017.1170, subp. 3 (A) and (B), and 40 CFR Section60.13(d)(1), for each pollutant concentration and diluent monitor. The calibrationdrift assessment shall be conducted on each monitor range. The Permittee shallcheck the zero (or low level value between 0 and 20 percent of span value) andspan (50 to 100 percent of span value) calibration drifts at least once eachoperating day. The zero and span must, at a minimum, be adjusted whenevereither the 24-hour zero drift or the 24-hour span drift exceeds two times the limit ofthe applicable performance specification in 40 CFR pt. 60, appendix B. The systemshall record and quantify the excess zero and span drift whenever specified.

6.0




12 Dec, 2014 09:18Page 72 of 73

Subject Item: MR 006 Opacity


SV 043 Boiler 7, 210-B07 [1]

NC/CA


S/A 40 CFR Section 60.7(a)(7); Minn.R. 7019.0100

Notification of compliance status: due 30 days before Performance Test required by40 CFR Section 60.8 if COMS data results will be used in lieu of 40 CFR, AppendixA, Method 9 observation data to determine compliance with the opacity standard asallowed by 40 CFR Section 60.11(e)(5).

1.0

CD 40 CFR Section 60.13(c)(1) & (2);Minn. R. 7017.1010

NSPS COMS Performance Evaluation Report: Due 10 days before theperformance test required under 40 CFR Section 60.8 and as described in Section60.11(e)(5) if the owner or operator of an affected facility elects to submit COMSdata In lieu of the performance test to demonstrate compliance with the opacitystandard. If instead the performance evalution is completed during the performancetest or within 30 days thereafter as allowed by Section 60.13(c), the report is duewithin 60 days of completion.

2.0

CD Minn. R. 7017.1180, subp. 2 COMS Calibration Error Audit Notification: due 30 days before the COMSCalibration Error Audit.

3.0

S/A Minn. R. 7017.1210, subp. 3 COMS Calibration Error Audit: due before end of each calendar half-year followingCOMS Calibration Error Audit. Audits are to be at least three months apart but nomore than eight months apart except that a calibration error audit need not beconducted during any semiannual period in which the emission unit operated lessthan 24 hours. The calibration error audit shall be conducted according to theprocedures in 40 CFR pt. 60, Appendix B, PS 1.

Filter values used shall correspond to approximately 11%, 20% and 37% opacity.

4.0

S/A Minn. R. 7017.1220 COMS Calibration Error Audit Results Summary: due 30 days after end of eachcalendar quarter following COMS Calibration Error Audit

5.0


COMS Daily Calibration Drift (CD) Test: The Permittee shall conduct dailycalibration drift assessments and make adjustments as needed according to theprocedure listed in 40 CFR Section 60.13(d)(1), for each opacity monitor. ThePermittee shall check the zero and upscale (span) calibration drifts at least oncedaily. The acceptable range of zero and upscale calibration materials is defined inthe applicable version of 40 CFR pt. 60, appendix B, PS-1. The optical surfaces,exposed to the effluent gases, shall be cleaned before performing the zero andupscale drift adjustments, except for systems using automatic zero adjustments.The optical surfaces shall be cleaned when the cumulative automatic zerocompensation exceeds 4 percent opacity.

6.0




12 Dec, 2014 09:18Page 73 of 73

Subject Item: MR 007 Diluent O2


SV 043 Boiler 7, 210-B07 [1]

NC/CA



CEMS Cylinder Gas Audit (CGA): due before end of each calendar half-yearfollowing CEM Certification Test for O2 CEMS. Conduct the CGA on eachconcentration and diluent monitor. The CGA shall be conducted on each monitorrange. Conduct the CGA at least 3 months apart and not greater than 8 monthsapart. If a RATA is performed during the calendar half-year the CGA is notrequired. Follow the procedures in 40 CFR pt. 60, Appendix F, section 5.1.2.

1.0



2.0

S/A Minn. R. 7017.1180, subp.1 Cylinder Gas Audit (CGA) Results Summary: due 30 days after end of eachcalendar half-year following end of the calendar quarter in which the Audit wasperformed for O2 CEMS.

3.0


4.0


5.0


O2 CEMS Daily Calibration Drift (CD) Test: The Permittee shall conduct dailycalibration drift assessments and make adjustments as needed according to theprocedure listed in Minn. R. 7017.1170, subp. 3 (A) and (B), and 40 CFR Section60.13(d)(1), for each pollutant concentration and diluent monitor. The calibrationdrift assessment shall be conducted on each monitor range. The Permittee shallcheck the zero (or low level value between 0 and 20 percent of span value) andspan (50 to 100 percent of span value) calibration drifts at least once eachoperating day. The zero and span must, at a minimum, be adjusted whenevereither the 24-hour zero drift or the 24-hour span drift exceeds two times the limit ofthe applicable performance specification in 40 CFR pt. 60, appendix B. The systemshall record and quantify the excess zero and span drift whenever specified.

6.0


Points Calculator

Points Calculator

1) AQ Facility ID No.: 12300694 Total Points 752) Facility Name: 3M - Administrative Offices - Maplewood3) Small business? y/n? n 4) DQ Numbers (including all rolled) : 4862, 4797, 4796, 4689, 4131, 3303, 2332, 2222, 212 5) Date of each Application Received: 7/9/14, 6/18/08, 2/2/10, 2/26/14, 9/26/12, 11/10/10, 11/21/08, 9/10/08, 6/18/086) Final Permit No. 12300694-0047) Permit Staff Cindy Schafer

8) "Work completed" in which .xls file (i.e. unit 2b, unit 1a, biofuels)? 3M

TotalApplication Type DQ No. Qty. Points Points DetailsAdministrative Amendment 3303 1 1 1Minor Amendment 2332, 4862 2 4 4 2332 received before fee ruleApplicability Request 10 0Moderate Amendment 4689 1 15 15Major Amendment 4131 1 25 25Individual State Permit (not reissuance) 50 0Individual Part 70 Permit (not reissuance) 75 0

Additional PointsModeling Review 15 0

BACT Review 15 0LAER Review 15 0CAIR/Part 75 CEM analysis 10 0NSPS Review 2332, 4689 2 10 20 subp. IIII, subp. JJJJNESHAP Review 4689 1 10 10 subp. ZZZZCase-by-case MACT Review 20 0Netting 10 0Limits to remain below threshold 10 0Plantwide Applicability Limit (PAL) 20 0AERA review 15 0Variance request under 7000.7000 35 0Confidentiality request under 7000.1300 2 0EAW reviewPart 4410.4300, subparts 18, item A; and 29 15 0Part 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 30

NOTES:

DQ 2123: Part 70 Reissuance; DQ 1231: Notification; DQ 4796: Notification; DQ 4797: Notification; DQ 2222: Reopening

(DQ DQ#)

technical support document for draft/proposed air …€¦ · technical support document, permit...

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