Technical Support Document for Draft Air Emission Permit No ......Technical Support Document, Permit Number: 08300056-101 Page 1 of 10 Technical Support Document for Draft Air Emission

Technical Support Document, Permit Number: 08300056-101 Page 1 of 10

Technical Support Document for

Draft Air Emission Permit No. 08300056-101 This technical support document (TSD) is intended for all parties interested in the draft 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 permit. 1. General information

1.1 Applicant and stationary source location Table 1. Applicant and source address

Applicant/Address Stationary source/Address (SIC Code: 4922 - Natural Gas Transmission)

Trans Canada 13710 FNB Pkwy Ste 300 Omaha, Nebraska 68154-5298

Northern Border Pipeline - Compressor 12 1270 260th Avenue Garvin, MN 56132

Contact: Ruth Jensen Phone: 402-492-7465

1.2 Facility description

Northern Border Pipeline Company (the Permittee) owns a natural gas pipeline that runs through the southwest corner of Minnesota. TransCanada is the operator of this pipeline. Primary sources of air emissions from the station are a 41,426 horsepower gas turbine and a 245 kilowatt (kW) emergency generator; the station also includes other small combustion units, all of which are classified as insignificant activities. The station is a major source under Part 70 and a non-major source under New Source Review.

1.3 Description of the activities allowed by this permit action

This permit action is Part 70 Reissuance. The permit does not authorize any specific projects, but allows replacement of components of the combustion turbine (EQUI 2), including replacements that would result in EQUI 2 being classified as a reconstructed unit subject to NSPS Subpart KKKK.

1.4 Facility emissions

Table 2. 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

All HAPs tpy

Total facility limited potential emissions 9.35 9.35 9.34 0.79** 239.2 98.23 166600 3.05 1.04 1.84 Total facility actual emissions (2016) 0.32 0.32 0.19 3.66** 67.33 16.16 126000 2.26 *

*Not reported in Minnesota emission inventory. ** Potential SO2 was calculated using a mass balance based on the amount of sulfur in natural gas and the capacity of the equipment to consume natural gas, assuming 1 pound of sulfur converts to 2 pounds of SO2. Actual SO2 emissions


were calculated based on a standard emission factor published in 2000. The actual emissions will be calculated using a mass balance, going forward. Table 3. Facility classification

Classification Major Synthetic minor/area Minor/Area New Source Review X Part 70 X Part 63 X

1.5 Changes to permit

The permit does not authorize any specific modifications, however, the MPCA has a combined operating and construction permitting program under Minnesota Rules Chapter 7007, and under Minn. R. 7007.0800, the MPCA has authority to include additional requirements in a permit. Under that authority, the following changes to the permit are also made through this permit action:

· The permit has been updated to reflect current MPCA templates and standard citation formatting.

· Completed requirements and the requirements for equipment that has been removed have been deleted.

· Some requirements have been reordered to help with clarity (i.e., similar requirements are grouped).

· The SO2 limits for EQUI 1 and EQUI 2 have been modified to reflect changes to Minnesota Rules; the new limits are effective in January 2018.

· STRU 9 was added to the permit; this is the stack associated with the waste heat recovery system, which was determined to be a separate source from Northern Border Pipeline Compressor Station 12 in 2008.

2. Regulatory and/or statutory basis

2.1 New source review (NSR)

The facility is a non-major source under NSR, due to federally enforceable limits on NOX emissions. No changes to that status are authorized through this permit action. This permit action does not authorize any changes subject to NSR.

The federally enforceable NOX emission limits result in annual PTE of 239.2 tons per year (Table 2), excluding insignificant activities. While this does not provide the 5-10% “cushion” below the NSR threshold that is recommended by EPA, the NOX PTE of the insignificant activities (combustion units described in Section 3.4) is known, and is 0.93 tons per year, for a total facility wide NOX PTE of 240.13 tons per year. The permittee is not allowed to make changes to the facility that would cause the PTE to exceed 250 tons per year, including changes that would qualify as insignificant modifications or minor or moderate amendments. In addition, the facility does not have a history of making changes to the facility. Therefore, the MPCA feels that the limits in the permit remain appropriate to adequately limit the potential emissions to below the NSR major source threshold for NOX.

2.2 Part 70 permit program

The facility is a major source under the Part 70 permit program.

2.3 New source performance standards (NSPS)

The combustion turbine (EQUI 2) is subject to NSPS Subpart GG – Standards of Performance for Stationary Gas Turbines. The Permittee is authorized to make certain changes to the combustion turbine that may make the unit subject to NSPS Subpart KKKK – Standards of Performance for Stationary Combustion Turbines.


The emergency generator (EQUI 1) is not subject to NSPS Subpart JJJJ – Standards of Performance for Stationary Spark Ignition Internal Combustion Engines, because it was installed in 1997, prior to the applicability date for Subpart JJJJ.

2.4 National emission standards for hazardous air pollutants (NESHAP)

EQUI 1 (emergency generator) is subject to area source requirements of NESHAP Subpart ZZZZ -- National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines.

EQUI 2 (combustion turbine) is not subject to any NESHAP at the time of permit issuance.

2.5 Compliance assurance monitoring (CAM)

CAM does not apply, because no add-on controls are used to meet emission limits.

2.6 Minnesota State Rules

EQUI 1 and EQUI 2 are subject to Minn. R. 7011.2300 Standards of Performance for Stationary Internal Combustion Engines Table 4. Regulatory overview of facility

Subject item* Applicable regulations Rationale

TFAC 1 - Air Quality Total Facility

40 CFR 1068 The facility includes portable air compressors and generators that qualify as non-road engines. These are stored at the compressor station site, but are used at remote sites where they can’t be stored.

Minn. R. 7009 The facility is subject to Ambient Air Quality Standards.

EQUI 1 - Reciprocating IC Engine

40 CFR 63, Subpart ZZZZ National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines. The engine was installed in 1997 and is therefore an existing emergency SI engine located at an area source.

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

EQUI 2 - Turbine

40 CFR 60, Subpart GG Standards of Performance for Stationary Gas Turbines. The gas turbine was installed in 1997, which is after the standard’s applicability date of October 3, 1997.

40 CFR 60, Subpart KKKK Standards of Performance for Stationary Combustion Turbines. This standard applies to combustion turbines that are constructed, modified, or reconstructed after February 18, 2005. The permit allows the permittee to routinely replace certain components of EQUI 2, which do not constitute modification. However, if the replacements are such that the constitute reconstruction, then Subpart KKKK will apply.

Minn. R. 7011.2300 Standards of Performance for Stationary Internal Combustion Engines. Combustion turbines are internal combustion engines.

Title I Condition: Avoid major modification under 40 CFR 52

EQUI 2 is subject to NOX limits under 40 CFR 60 Subpart GG, that also serve to limit total PTE to below major source thresholds under NSR.

*Location of the requirement in the permit (e.g., EQUI 1, STRU 2, etc.).

3. Technical information


3.1 Calculations of potential to emit (PTE)

Attachment 1 to this TSD contains detailed spreadsheets of calculations of the facility PTE. Potential emissions for EQUI 1 are based on equipment capacity and emission factors published in AP-42 Section 3.2 (for HAPs and all criteria pollutants except SO2) and 40 CFR 98 and the Climate Registry Default Emission factors (for greenhouse gases). Potential SO2 emissions for EQUI 1 are based on a mass balance of the potential amount of sulfur present in pipeline natural gas and a ratio of 2 pounds of SO2 per pound of sulfur. Potential emissions for EQUI 2 are based on permit limits for NOX, on worst-case calculated CO emissions based on load and ambient temperature for CO, and on equipment capacity and emission factors published in AP-42 Table 3.1-2a and 3.1-3 (for remaining criteria pollutants and HAPs), and 40 CFR 98 and the Climate Registry Default Emission factors (for greenhouse gases). Attachment 2 includes a summary of the PTE calculations.

3.2 Dispersion modeling

Per MPCA policy, as permitted in the original Part 70 permit, the facility triggered the requirement to complete air dispersion modeling to show modeled compliance with the nitrogen dioxide national ambient air quality standards (NAAQS). Per MPCA practice, a table of the modeled parameters was added to the previous permit (08300056-002) as an appendix; the appendix is carried forward to this permit. Additional modeling was submitted in 2009, to demonstrate that the addition of the waste heat recovery system did not cause adverse ambient impacts. The parameters listed in Appendix B of the permit describe the operation of the facility at maximum capacity. In other words, the flow rates and temperatures listed in Appendix B represent the minimum parameters at the maximum emission rates. The MPCA does not require any specific compliance demonstration with these parameters because they are worst-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 5. Modeling Parameters and Modeled Impacts

Stack Height (m)

Equivalent Diameter (m)

% load Exit Velocity (m/s)

Exit Temperature (degrees K)

NOX Emissions (g/sec)

Maximum Modeled Impact (µm/m3)

Annual Standard (µm/m3)

STRU 1 16.76 3.52

60% 15.99 598.16 5.51

58.5 100

75% 18.31 618.16 6.03 90% 18.31 618.16 6.62 100% 21.35 664.83 6.62

STRU 9 18.3 3.3

60% 11.8 383.15 5.51 75% 13.6 398.15 6.03 90% 13.6 398.15 6.62 100% 14.7 398.15 6.62

STRU 2 5.2 0.20 NA 30.5 699.82 1.78

At this time, modeling is being required to demonstrate compliance with the 1-hour nitrogen dioxide ambient air quality standard.


3.3 Monitoring

In accordance with the Clean Air Act, it is the responsibility of the owner or operator of a facility to have sufficient knowledge of the facility to certify that the facility is in compliance with all applicable requirements.

In evaluating the monitoring included in the permit, the MPCA considered the following:

· the likelihood of the facility violating the applicable requirements; · whether add-on controls are necessary to meet the emission limits; · the variability of emissions over time; · the type of monitoring, process, maintenance, or control equipment data already available for the

emission unit; · the technical and economic feasibility of possible periodic monitoring methods; and · the kind of monitoring found on similar units elsewhere.

Table 6 summarizes the monitoring requirements. Table 6. Monitoring

Subject Item* Requirement (basis)

What is the monitoring? Why is this monitoring adequate?

EQUI 1 Sulfur Dioxide <= 0.50 pounds per million Btu heat input. [Minn. R. 7011.2300, subp. 2(A)]

None Potential emissions based on equipment capacity and allowable fuels are 0.0006 lb/MMBtu.

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

None Based on the low potential emissions of particulate matter and sulfur dioxide due to the allowable fuels, significant opacity is not expected.

EQUI 1 Sulfur Dioxide <= 0.0015 pounds per million Btu heat input. [Minn. R. 7011.2300, subp. 2(B)]


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





EQUI 2 Sulfur Dioxide <= 0.0015 pounds per million Btu heat input. [Minn. R. 7011.2300, subp. 2(B)]


EQUI 2 Opacity <= 20 percent opacity once operating temperatures have been attained. [Minn. R. 7011.2300, subp. 1]

None Based on the low potential emissions of particulate matter and sulfur dioxide due to the allowable fuels, significant opacity is not expected.

EQUI 2 Sulfur Dioxide <= 0.015 percent by volume at 15 percent oxygen and on a dry basis. [40 CFR 60.333, Minn. R. 7011.2350]

None The calculated sulfur content of the fuel is 0.007 weight percent, which is 0.8 percent of the NSPS limit. It is reasonable to assume that the potential SO2 emission rate is also a small fraction of the emission limit.

EQUI 2 Sulfur Content of Fuel <= 0.8 percent by weight. [40 CFR 60.333, Minn. R. 7011.2350]

None Natural gas is the only fuel burned. NSPS allows for no sulfur monitoring if the only fuel burned is natural gas.

EQUI 2 Nitrogen Oxides <= 0.0217 percent by volume at 15 percent oxygen and on a dry basis. [40 CFR 60.332(a)(2), Minn. R. 7011.2350]

None Natural gas is the only fuel burned. The custom monitoring plan (see Attachment 3 to this TDS) provides that no monitoring of fuel nitrogen content is required if natural gas is the only fuel fired.




EQUI 2 Nitrogen Oxides <= 52.5 pounds per hour during DLE** operation. [40 CFR 60.332(a)(2), Minn. R. 7011.2350, Title I Condition: Avoid major source under 40 CFR 52.21(b)(1)(i) and Minn. R. 7007.3000]

Performance testing

A performance test is required within 90 days of any component replacement, as allowed by the permit. Component replacement occurs every 24000 – 25000 operating hours, which results in testing being required once every 3-4 years, on average. This frequency is consistent with what would be required if it were based on test results.

EQUI 2 Nitrogen Oxides <= 78 pounds per hour during non-DLE** operation. [40 CFR 60.332(a)(2), Minn. R. 7011.2350, Title I Condition: Avoid major source under 40 CFR 52.21(b)(1)(i) and Minn. R. 7007.3000]

Performance testing

A performance test is required within 90 days of any component replacement, as allowed by the permit. Component replacement occurs every 24000 – 25000 operating hours, which results in testing being required once every 3-4 years, on average. This frequency is consistent with what would be required if it were based on test results.

EQUI 2 Sulfur Dioxide <= 110 nanograms per joule (0.90 lb/MWh) gross output or the Permittee must not burn any fuel in EQUI 2 which contains total potential sulfur emissions in excess of 26 ng SO2/J (0.060 lb SO2/MMBtu) heat input. [40 CFR 60.4330(a), Minn. R. 7011.2375]

None At this time, the limit does not apply because EQUI 2 is not a reconstructed unit.




EQUI 2 Reconstructed Units: The Permittee shall limit emissions of Nitrogen Oxides <= 150 parts per million at 15 percent O2 or 1,100 ng/J of useful output (8.7 lb/MWh) when turbine is operating at less than 75 percent of peak load or operating at temperatures less than 0 deg F. [40 CFR 60.4320(a)]

Performance test Initial performance test is required after EQUI 2 is reconstructed.

EQUI 2 Reconstructed Units: The Permittee shall limit emissions of Nitrogen Oxides <= 42 parts per million at 15 percent O2 or 250 ng/J of useful output (2.0 lb/MWh) when turbine is operating at or above 75 percent of peak load and when operating at 0 deg F or above. [40 CFR 60.4320(a)]

Performance test Initial performance test is required after EQUI 2 is reconstructed.




EQUI 2 Operation in non-DLE mode <= 500 hours per year on a 12-month rolling sum [Title I condition: Avoid manor source under 40 CFR 52.21(b)(1)(i) and Minn. R. 7007.3000]

Daily recordkeeping, monthly calculations

Allows verification of compliance at any time.

*Location of the requirement in the permit (e.g., EQUI 1, STRU 2, etc.). ** DLE means “Dry-Low Emissions”, a form of staged combustion in which NOX emissions are lowered via a low-oxygen environment or a low-temperture environment. The turbine can’t always run in DLE mode, but time of non-DLE operation is limited by permit conditions.

3.4 Insignificant activities

Northern Border Pipeline - Compressor 12 has several operations which are classified as insignificant activities under the MPCA’s permitting rules. These are listed in Appendix A to the permit.

The permit is required to include periodic monitoring for all emissions units, including insignificant activities, per EPA guidance. The insignificant activities at this Facility are only subject to general applicable requirements. Using the criteria outlined earlier in this TSD, the following table documents the justification why no additional periodic monitoring is necessary for the current insignificant activities. See Attachment 1 of this TSD for PTE information for the insignificant activities. Table 7. Insignificant activities

Insignificant activity General applicable emission limit Discussion

Fuel Use: space heaters fueled by kerosene, natural gas, or propane, less than 420,000 Btu/hr

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

100,000 Btu/hour gas fired space heater. PM emissions based on equipment capacity and published emission factors are 0.0075 lb/MMBtu.

Indirect heating equipment with a capacity less than 420,000 Btu/hour, etc.

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

Three gas fired furnaces at 120,000 Btu/hour each. PM emissions based on equipment capacity and published emission factors are 0.0075 lb/MMBtu.

Brazing, soldering or welding equipment

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

This is a maintenance operation, performed on an intermittent basis. Significant PM emissions are not expected.


Insignificant activity General applicable emission limit Discussion

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

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

Parts washer: PM, variable depending on airflow Opacity <= 20% (Minn. R. 7011.0710.0715)

1.67 MMBtu/hour gas fired boiler. PM emissions based on equipment capacity and published emission factors are 0.0075 lb/MMBtu.

Fugitive dust emissions from unpaved entrance roads and parking lots

Requirement to take reasonable measures to prevent PM from becoming airborne (Minn. R. 7011.0150)

There is not significant vehicle traffic.

3.5 Permit organization

In this permit, federal requirements from NESHAPs and NSPS are included in two different formats. The requirements for 40 CFR pt. 60, subps. GG, KKKK, and A are incorporated into the permit as individual permit requirements, which has historically been MPCA’s standard practice. However, the requirements for 40 CFR pt. 63, subp. ZZZZ and the associated General Provisions in 40 CFR pt. 63, subp. A are included in a different way.

For these rules, limits and submittal/actions are included individually in the permit like the other standards. For the remaining portions of the rule, a requirement in Section 5 of the permit lists the citations of all of the applicable parts of the standard along with a reference to the permit appendix where the full text of the standard is included. 40 CFR pt. 63, subp. ZZZZ and 40 CFR pt. 63, subp. A are included in Appendices C and D, respectively.

In other respects, the permit meets the MPCA Tempo Guidance for ordering and grouping of requirements.

3.6 Comments received

4. Permit fee assessment

This permit action is the reissuance of an individual Part 70; therefore, no application fees apply under Minn. R. 7002.0016, subp. 1.

5. Conclusion Based on the information provided by Northern Border Pipeline - Compressor 12 the MPCA has reasonable assurance that the proposed operation of the emission facility, as described in the Air Emission Permit No. 08300056-101 and this TSD, will not cause or contribute to a violation of applicable federal regulations and Minnesota Rules. Staff members on permit team: Toni Volkmeier (permit engineer)


Adriane Lorsung (peer reviewer) Patrick Connerton (Enforcement) Curtis Stock (Compliance) Joe Handtmann (permit writing assistant) Laurie O’Brien (administrative support)

TEMPO360 Activities: Part 70 Reissuance (IND20100001)

Attachments: 1. Calculation spreadsheets 2. Subject item inventory, PTE summary, and facility requirements 3. Custom NOX monitoring plan 4. Excerpts from Modeling Results document

Attachment 1 –Calculation Spreadsheets

CAS EQUI 2 EQUI 1 TotalPollutant Number (ton/yr) (ton/yr) (ton/yr)

NOx 236.325 2.90 239.22CO 98.112 0.23 98.34

VOC 2.97 0.08 3.05PM10 9.34 0.01 9.34SO2 0.79 0.00 0.79PM 9.34 0.01 9.34

PM2.5 9.34 0.01 9.34Acenaphthene 83-32-9 8.88E-07 8.88E-07

Acenaphthylene 208-96-8 3.93E-06 3.93E-06Acetaldehyde 75-07-0 5.66E-02 5.94E-03 6.25E-02

Acrolein 107-02-8 9.05E-03 3.65E-03 1.27E-02Benzene 71-43-2 1.70E-02 3.12E-04 1.73E-02

Benzo(a)anthracene 56-55-3 4.24E-03 4.24E-03Benzo(b)fluoranthene 205-99-2 1.18E-07 1.18E-07

Benzo(e)pyrene 192-97-2 2.95E-07 2.95E-07Benzo(g,h,i)perylene 191-24-2 2.94E-07 2.94E-07

Biphenyl 92-52-4 1.51E-04 1.51E-041,3-Butadiene 106-99-0 6.08E-04 1.90E-04 7.98E-04

Cadmium 7440-43-9 9.79E-03 9.79E-03Carbon Tetrachloride 56-23-5 2.61E-05 2.61E-05

Chlorobenzene 108-90-7 2.16E-05 2.16E-05Chloroform 67-66-3 2.02E-05 2.02E-05Chromium 7440-47-3 1.87E-02 1.87E-02Chrysene 218-01-9 4.92E-07 4.92E-07

1,3-Dichloropropene 542-75-6 1.87E-05 1.87E-05Ethylbenzene 100-41-4 4.53E-02 2.82E-03 4.81E-02

Ethylene Dibromide 106-93-4 3.15E-05 3.15E-05Fluoranthene 206-44-0 1.70E-03 7.88E-07 1.70E-03

Fluorene 86-73-7 4.03E-06 4.03E-06Formaldehyde 50-00-0 1.00E+00 3.75E-02 1.04E+00

Manganese 7439-96-5 1.13E-01 1.13E-01Mercury 7439-97-6 9.38E-03 9.38E-03Methanol 67-56-1 1.78E-03 1.78E-03

Methylene Chloride 75-09-2 1.42E-05 1.42E-052-Methylnaphthalene 91-57-6 2.36E-05 2.36E-05

n-Hexane 110-54-3 7.88E-04 7.88E-04Naphthalene 91-20-3 1.84E-03 5.28E-05 1.89E-03

Nickel 7440-02-0 1.63E-01 1.63E-01PAH NA 3.11E-03 1.91E-05 3.13E-03

Phenanthrene 85-01-8 7.38E-06 7.38E-06Phenol 108-95-2 1.80E-02 1.70E-05 1.80E-02

Propylene 115-07-1 0.00E+00Pyrene 129-00-0 9.66E-07 9.66E-07

Perylene 198-55-0 0.00E+00Propylene Oxide 198-55-0 4.10E-02 4.10E-02

Styrene 100-42-5 1.68E-05 1.68E-05Toluene 108-88-3 1.84E-01 2.90E-04 1.84E-01

Tetrachloroethane 79-34-5 1.76E-06 1.76E-061,1,2,2-Tetrachloroethane 79-34-5 2.84E-05 2.84E-05

1,1,2-Trichloroethane 79-00-5 2.26E-05 2.26E-052,2,4-Trimethylpentane 540-84-1 1.78E-04 1.78E-04

Vinyl Chloride 75-01-4 1.06E-05 1.06E-05Xylene 108-38-3 9.05E-02 1.31E-04 9.07E-02

Total HAP 1.791 0.0540 1.85CO2 165383 83 165466

Methane 11.86 0.16 12.02Nitrous Oxide 2.80 0.00 2.80

CO2e 166514 87 166601

Site Potential-To-Emit Summary

Northern Border Pipeline CompanyCompressor Station No. 12 (Garvin, Minnesota)

Permit No. 08300056-101

Emission Unit ID: EQUI 1Description: Waukesha F18GL generator engine

Rating: 245 kilowatts (kW)Rating: 350 horsepower

Heat Input: 2.84 million British thermal units per hour (MMBtu/hr)Fuel Type: Natural Gas

Controls: NoneConversion: 2,000 lb/tonConversion: 500 hours per year

Emission EmissionPollutant Factor Factor Units (lb/hr) (ton/yr)

NOX 4.08 lb/MMBtu 11.6 2.90

CO 0.317 lb/MMBtu 0.9 0.23

VOC 1.18E-01 lb/MMBtu 0.34 0.084PM10 9.91E-03 lb/MMBtu 0.028 0.007SO2 5.88E-04 lb/MMBtu 0.002 0.0004

0.0006 lb/mmbtuNote: The criteria pollutant emission factors are the same as those used in the previous Title V permit application. The fuel input has been updated to reflect the actual rating of the engine. (AP-42 Table 3.2-2)

Example calculations:NOX lb/hr: (2.84 MMBtu/hr) * (4.08 lb/MMBtu) = 11.59 lb/hr NOx

NOX ton/yr: (11.6 lb/hr) * (500 hr/yr) / (2,000 lb/ton) = 2.90 ton/yr NOx

CO lb/hr: (2.84 MMBtu/hr) * (0.317 lb/MMBtu) = 0.90 lb/hr CO

CO ton/yr: (0.90 lb/hr) * (500 hr/yr) / (2,000 lb/ton) = 0.23 ton/yr CO

VOC lb/hr: (2.84 MMBtu/hr) * (0.118 lb/MMBtu) = 0.34 lb/hr VOC

VOC ton/yr: (0.34 lb/hr) * (500 hr/yr) / (2,000 lb/ton) = 0.08 ton/yr VOCPM10 lb/hr: (2.84 MMBtu/hr) * (0.0099 lb/MMBtu) = 0.03 lb/hr PM10

PM10 ton/yr: (0.03 lb/hr) * (500 hr/yr) / (2,000 lb/ton) = 0.01 ton/yr PM10

SO2 lb/hr: (2.84 MMBtu/hr) * (0.0006 lb/MMBtu) = 0.002 lb/hr SO2

SO2 ton/yr: (0.002 lb/hr) * (500 hr/yr) / (2,000 lb/ton) = 0.0004 ton/yr SO2

Greenhouse Gaseslb/MMBtua GWP Lb/hr TPY Lim

CO2 116.9 1 332 1454 82.999Methane 0.23 25 0.65 2.86 0.1633Nitrous Oxide 0.00022 298 6.25E-04 2.74E-03 0.00016CO2e 349 1526 87.128

a CO2 is from Table C-1 of 40 CFR 98 Subpart C; CH4 is from Tab;e C-2 of 40 CFR 98 Subpart D; N20 is from Table 12.7 of the Climate Registry Default Emission Factors

EQUI 1 Criteria Air Pollutant Calculations


Permit No. 08300056-101

Emission Unit ID: EQUI 1Description: Waukesha F18GL generator engine

Rating: 245 kilowatts (kW)Rating: 350 horsepower

Heat Input: 2.84 million British thermal units per hour (MMBtu/hr)Fuel Type: Natural Gas

Controls: NoneConversion: 2,000 lb/tonConversion: 500 hours per year

CAS Emission EmissionPollutant Number Factor Factor Units (lb/hr) (ton/yr)

Acenaphthene 83-32-9 1.25E-06 lb/MMBtu 3.55E-06 8.88E-07Acenaphthylene 208-96-8 5.53E-06 lb/MMBtu 1.57E-05 3.93E-06

Acetaldehyde 75-07-0 8.36E-03 lb/MMBtu 2.37E-02 5.94E-03Acrolein 107-02-8 5.14E-03 lb/MMBtu 1.46E-02 3.65E-03Benzene 71-43-2 4.40E-04 lb/MMBtu 1.25E-03 3.12E-04

Benzo(b)fluoranthene 205-99-2 1.66E-07 lb/MMBtu 4.71E-07 1.18E-07Benzo(e)pyrene 192-97-2 4.15E-07 lb/MMBtu 1.18E-06 2.95E-07

Benzo(g,h,i)perylene 191-24-2 4.14E-07 lb/MMBtu 1.18E-06 2.94E-07Biphenyl 92-52-4 2.12E-04 lb/MMBtu 6.02E-04 1.51E-04

1,3-Butadiene 106-99-0 2.67E-04 lb/MMBtu 7.58E-04 1.90E-04Carbon Tetrachloride 56-23-5 3.67E-05 lb/MMBtu 1.04E-04 2.61E-05

Chlorobenzene 108-90-7 3.04E-05 lb/MMBtu 8.63E-05 2.16E-05Chloroform 67-66-3 2.85E-05 lb/MMBtu 8.09E-05 2.02E-05Chrysene 218-01-9 6.93E-07 lb/MMBtu 1.97E-06 4.92E-07

1,3-Dichloropropene 53-70-3 2.64E-05 lb/MMBtu 7.50E-05 1.87E-05Ethylbenzene 100-41-4 3.97E-03 lb/MMBtu 1.13E-02 2.82E-03

Ethylene Dibromide 106-93-4 4.43E-05 lb/MMBtu 1.26E-04 3.15E-05Fluoranthene 206-44-0 1.11E-06 lb/MMBtu 3.15E-06 7.88E-07

Fluorene 86-73-7 5.67E-06 lb/MMBtu 1.61E-05 4.03E-06Formaldehyde 50-00-0 5.28E-02 lb/MMBtu 1.50E-01 3.75E-02

Methanol 67-56-1 2.50E-03 lb/MMBtu 7.10E-03 1.78E-03Methylene Chloride 75-09-2 2.00E-05 lb/MMBtu 5.68E-05 1.42E-05

2-Methylnaphthalene 91-57-6 3.32E-05 lb/MMBtu 9.43E-05 2.36E-05n-Hexane 110-54-3 1.11E-03 lb/MMBtu 3.15E-03 7.88E-04

Naphthalene 91-20-3 7.44E-05 lb/MMBtu 2.11E-04 5.28E-05Phenol 108-95-2 2.40E-05 lb/MMBtu 6.82E-05 1.70E-05PAH 85-01-8 2.69E-05 lb/MMBtu 7.64E-05 1.91E-05

Phenanthrene 115-07-1 1.04E-05 lb/MMBtu 2.95E-05 7.38E-06Pyrene 198-55-0 1.36E-06 lb/MMBtu 3.86E-06 9.66E-07Styrene 100-42-5 2.36E-05 lb/MMBtu 6.70E-05 1.68E-05Toluene 108-88-3 4.08E-04 lb/MMBtu 1.16E-03 2.90E-04

Tetrachloroethane 79-34-5 2.48E-06 lb/MMBtu 7.04E-06 1.76E-061,1,2,2-Tetrachloroethane 79-34-5 4.00E-05 lb/MMBtu 1.14E-04 2.84E-05

1,1,2-Trichloroethane 79-00-5 3.18E-05 lb/MMBtu 9.03E-05 2.26E-052,2,4-Trimethylpentane 540-84-1 2.50E-04 lb/MMBtu 7.10E-04 1.78E-04

Vinyl Chloride 75-01-4 1.49E-05 lb/MMBtu 4.23E-05 1.06E-05Xylene 108-38-3 1.84E-04 lb/MMBtu 5.23E-04 1.31E-04

Total HAPs 0.2162 0.0540

The emission factors are based on AP-42, Uncontrolled Emission Factors for4-Stroke Lean Burn Engines , Table 3.2-2 (July 2000).

Example calculations:

Acetaldehyde lb/hr: (0.00836 lb/MMBtu) * (2.84 MMBtu/hr) = 0.02 lb/hr Acetaldehyde

Acetaldehyde ton/yr: (0.02 lb/hr) * (500 hr/yr) / (2,000 lb/ton) = 0.006 ton/yr Acetaldehyde

Emissions


Permit No. 08300056-101EQUI 1 Hazardous Air Pollutant Calculations

Emission Unit ID: EQUI 2Description: Cooper-Rolls Coberra 6562-DLE Compressor Turbine

Rating: 38,000 horsepower (ISO)Max. Heat Input: 323 million British thermal units per hour (MMBtu/hr)

Fuel Type: Natural GasControls: Dry low NOx combustion

Wt% Sulfur: 0.007 2.0 grains per 100 scf = 0.007 Weight PercentConversion: 2,000 lb/tonConversion: 8,760 hours per year

500 hours per year non-DLE8,260 hours per year DLE

Emission EmissionPollutant Factor Factor Units (lb/hr) (ton/yr) Limited

NOX (DLE)a 52.5 lb/hr 52.5 217 236.325NOX (non-DLE)a 78.0 lb/hr 78.0 19.5NOX total unres. 78.0 683.3

COa 22.4 lb/hr 22.4 98.1VOCb 0.0021 lb/MMBtu 0.68 2.97PM10

b 0.0066 lb/MMBtu 2.1 9.34SO2

c 0.2 0.79

0.00056aNOx (DLE) and CO factors are based on manufacturer's data, approved through previous permit actions. NOX (Non-DLE) is baed on performance testing done by the facility, also approved through previous permit acti bVOC and PM10 are based on AP-42, Table 3.1-2a (April 2000); PM and PM2.5 assumed the same as PM10cSO2 is based on a mass balance (see below)

Example calculations:NOx (DLE) ton/yr: (52.5 lb/hr) * (8,260 hr/yr) / (2,000 lb/ton) = 217 ton/yr NOxNOx (non-DLE) ton/yr: (78.0 lb/hr) * (500 hr/yr) / (2,000 lb/ton) = 20 ton/yr NOx

CO ton/yr: (22.4 lb/hr) * (8,760 hr/yr) / (2,000 lb/ton) = 98 ton/yr COVOC lb/hr: (0.0021 lb/MMBtu) * (323 MMBtu/hr) = 0.68 lb/hr VOC

VOC ton/yr: (0.68 lb/hr) * (8,760 hr/yr) / (2,000 lb/ton) = 3.0 ton/yr VOCPM10 lb/hr: (0.0066 lb/MMBtu) * (323 MMBtu/hr) = 2.1 lb/hr PM10

PM10 ton/yr: (2.1 lb/hr) * (8,760 hr/yr) / (2,000 lb/ton) = 9.3 ton/yr PM10SO2 Lb/hr: (2000 gr S/mmcf) x (1 mmcf/1020 mmBtu) x (323 mmBtu/hr) x (1 lb S/7000 gr S) x (2 lb SO

0.180952 lb/hr SO2

Greenhouse Gaseslb/MMBtuc GWP Lb/hr TPY

CO2 116.9 1 37759 165383Methane 0.00838 25 2.71 11.86Nitrous Oxide 0.00198 298 0.64 2.80CO2e 38017 166514

c CO2 is from Table C-1 of 40 CFR 98 Subpart C; CH4 and N2O are from Table 12.7 of the Climate Registry Default Emission Factors

40 CFR 72.2:

Pipeline natural gas means a naturally occurring fluid mixture of hydrocarbons (e.g., methane, ethane, or propane) produced in geological formations beneath the Earth's surface that maintains a gaseous state at standard atmospheric temperature and pressure under ordinary conditions, and which is provided by a supplier through a pipeline. Pipeline

natural gas contains 0.5 grains or less of total sulfur per 100 standard cubic feet. Additionally, pipeline natural gas must either be composed of at least 70 percent methane by volume or have a gross calorific value between 950 and 1100 Btu

per standard cubic foot

Emissions


Permit No. 08300056-101EQUI 2 Criteria Air Pollutant Calculations

see below

Emission Unit ID: EQUI 2Description: Cooper-Rolls Coberra 6562-DLE Compressor Turbine

Rating: 38,000 horsepower (ISO)Max. Heat Input: 323 million British thermal units per hour (MMBtu/hr)

Fuel Type: Natural GasControls: Dry low NOx combustion

Wt% Sulfur: 0.007 2.0 grains per 100 scf = 0.007 Weight PercentConversion: 2,000 lb/tonConversion: 8,760 hours per year

500 hours per year non-DLE8,260 hours per year DLE

HAPc Lb/hr TPYAcetaldehyde 4.00E-05 lb/MMBtu 1.29E-02 5.66E-02

Acrolein 6.40E-06 lb/MMBtu 2.07E-03 9.05E-03Benzene 1.20E-05 lb/MMBtu 3.88E-03 1.70E-02

Benzo(a)anthracene 3.00E-06 lb/MMBtu 9.69E-04 4.24E-031,3-Butadiene 4.30E-07 lb/MMBtu 1.39E-04 6.08E-04

Cadmium 6.92E-06 lb/MMBtu 2.24E-03 9.79E-03Chromium 1.32E-05 lb/MMBtu 4.26E-03 1.87E-02

Ethylbenzene 3.20E-05 lb/MMBtu 1.03E-02 4.53E-02Fluoranthene 1.20E-06 lb/MMBtu 3.88E-04 1.70E-03Formaldehyde 7.10E-04 lb/MMBtu 2.29E-01 1.00E+00

Manganese 8.02E-05 lb/MMBtu 2.59E-02 1.13E-01Mercury 6.63E-06 lb/MMBtu 2.14E-03 9.38E-03

Naphthalene 1.30E-06 lb/MMBtu 4.20E-04 1.84E-03Nickel 1.15E-04 lb/MMBtu 3.71E-02 1.63E-01Phenol 1.27E-05 lb/MMBtu 4.10E-03 1.80E-02PAH 2.20E-06 lb/MMBtu 7.11E-04 3.11E-03

Propylene Oxide 2.90E-05 lb/MMBtu 9.37E-03 4.10E-02Toluene 1.30E-04 lb/MMBtu 4.20E-02 1.84E-01Xylene 6.40E-05 lb/MMBtu 2.07E-02 9.05E-02

Total HAP 0.41 1.791

NOX, CO, SO2, PM10 and VOC emission factors have not changed from previous application.

aNOx and CO factors are based on manufacturer's data.bSO2, VOC and PM10 are based on AP-42, Table 3.1-2a (April 2000)c HAP emission factors based on AP-42, Table 3.1-3 (April 2000) for natural gas-fired turbines and EPA FIRE Database (Version 6.23).

Example calculations:

Acrolein lb/hr: (0.0000064 lb/MMBtu) * (323 MMBtu/hr) = 0.002 lb/hr Acrolein

Acrolein ton/yr: (0.002 lb/hr) * (8,760 hr/yr) / (2,000 lb/ton) = 0.01 ton/yr Acrolein


Permit No. 08300056-101EQUI 2 Criteria Air Pollutant Calculations

Attachment 2 – Subject item inventory and facility requirements

Agency Interest Name Subject Item ID SI Designation and Description

Northern BorderPipeline - Compressor12

ACTV1NullAll IA's

AISI4118NullNull

EQUI1EU002Emergency Generator

EQUI2EU001Gas Turbine

STRU1SV001Turbine

STRU2SV002Emergency Generator

STRU3BG001Compressor Building

STRU4BG002Auxiliary Building

STRU5BG003Fuel Gas Utility Building

STRU6BG004Microwave Building

STRU7BG005Gas Coolers

STRU8 NullValve Shelter

List of SIs

Agency Interest: Northern Border Pipeline -Compressor 12Agency Interest ID: 4118Activity: IND20100001 (Part 70 Reissuance)

Details for:SI Category: NoneSI Type: All

Agency Interest Name Subject Item ID SI Designation and DescriptionNorthern BorderPipeline - Compressor12


STRU8NullValve Shelter

STRU9NullWHOH

TFAC108300056Northern Border Pipeline -Compressor 12

List of SIs

Agency Interest: Northern Border Pipeline -Compressor 12Agency Interest ID: 4118Activity: IND20100001 (Part 70 Reissuance)

Details for:SI Category: NoneSI Type: All

Agency Interest Na.. Activity ID Subject Ite..Subject Item Type Description Subject Item ID SI Designation and Description Status Desc..Sub Attribute Description

Northern BorderPipeline - Compressor12

IND20100001 Activity Insignificant Air Emissions Activity ACTV1 NullAll IA's

Null Minn. R. 7007.1300, subp. 3(A)

Minn. R. 7007.1300, subp.3(B)(2)

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

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

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

Insignificant air emissions activity

Agency Interest: Northern Border Pipeline - Compressor 12Agency Interest ID: 4118Activity: IND20100001 (Part 70 Reissuance)

Details for:SI Category: ActivitySI Type: Insignificant Air Emissions Activity

Subject ItemCategory Description

Subject Item TypeDescription Subject Item ID

Subject ItemDesignation Subject Item Description Pollutant

Potential (lbs/hr)

Unrestricted Potential

(tons/yr)

Potential Limited

(tons/yr)

Actual Emissions

(tons/yr)

Equipment Reciprocating IC EngineEQUI1 EU002 Emergency Generator 1,1,2-Trichloroethane

1,1,2,2-Tetrachloroethane

1,2-Dibromoethane (Ethyl..

1,3-Butadiene

1,3-Dichloropropene

2-Methylnaphthalene

2,2,4-trimethylpentane

Acenaphthene

Acenaphthylene

Acetaldehyde

Acrolein

Benzene

Benzo(b)fluoranthene

Benzo(e)pyrene

Benzo(ghi)perylene

Biphenyl

Carbon Dioxide

Carbon Dioxide Equivalent

Carbon Monoxide

Carbon tetrachloride

Chlorobenzene (Monochlo..

Chloroform

Chrysene

Dichloromethane (Methyl..

Ethylbenzene

Fluoranthene

Fluorene

Formaldehyde

HAPs - Total

Hexane

Methane

Methanol

Naphthalene

Nitrogen Oxides

Nitrous Oxide

Particulate Matter

Phenanthrene

Phenol

PM < 10 micron

Pyrene

Styrene

Sulfur Dioxide

Tetrachloroethylene (Per..

Toluene

Vinyl chloride (chloroethe..

Volatile Organic Compoun..

Xylenes, Total

Turbine EQUI2 EU001 Gas Turbine 1,3-Butadiene

Acetaldehyde

Acrolein

Benzene

Benzo(a)anthracene

Cadmium compounds

Carbon Dioxide

Carbon Dioxide Equivalent

Carbon Monoxide

Chromium compounds

Ethylbenzene

Fluoranthene

Formaldehyde

HAPs - Total

Manganese compounds

Methane

Naphthalene

Nickel compounds

0.0001310.08

1.06e-050.000291.76e-060.0004171.68e-059.66e-07

0.011.7e-057.38e-06

0.010.000156

2.95.28e-050.001780.16

0.0007880.0540.03754.03e-067.88e-070.002824.12e-054.92e-072.02e-052.16e-052.61e-05

0.238783

0.0001512.94e-072.95e-071.18e-070.0003120.003650.005943.93e-068.88e-070.0001782.36e-051.87e-050.000193.15e-052.84e-052.26e-05

0.002291.47

0.0001850.005083.08e-050.007310.0002941.69e-05

0.120.0002990.000129

0.120.0027450.75

0.0009250.03112.86

0.01380.9470.657

7.05e-051.38e-050.0494

0.0002498.62e-060.0003550.0003780.000457

3.941,5261,454

0.002645.15e-065.16e-062.06e-060.005470.06390.104

6.88e-051.55e-050.003110.0004130.0003280.003320.0005510.0004980.000396

0.0005230.34

4.23e-050.001167.04e-060.001676.7e-053.86e-06

0.036.82e-052.95e-05

0.030.00062511.59

0.0002110.00710.65

0.003150.21620.15

1.61e-053.15e-060.01135.68e-051.97e-068.09e-058.63e-050.000104

0.9349332

0.0006021.18e-061.18e-064.71e-070.001250.01460.02371.57e-053.55e-060.000719.43e-057.5e-05

0.0007580010.0001260.0001149.03e-05

0.0018411.860.1131.791

0.00170.04530.0187

98166,514165,3830.009790.004240.017

0.009050.0566

0.000608

0.0018411.860.1131.791

0.00170.04530.0187

98166,514165,3830.009790.004240.017

0.009050.0566

0.000608

0.000422.710.0260.410.229

0.0003880.01030.0042622.4

38,01737,7590.002240.0009690.003880.002070.0129

0.000139

PTE by subject item

Agency Interest: NoneAgency Interest ID: 4118Activity: None (Part 70 Reissuance)

Details for:SI Category: EquipmentSI Type: All

Subject ItemCategory Description

Subject Item TypeDescription Subject Item ID

Subject ItemDesignation Subject Item Description Pollutant

Potential (lbs/hr)

Unrestricted Potential

(tons/yr)

Potential Limited

(tons/yr)

Actual Emissions

(tons/yr)

Equipment Turbine EQUI2 EU001 Gas TurbineNaphthalene

Nickel compounds

Nitrogen Oxides

Nitrous Oxide

Particulate Matter

Phenol

PM < 2.5 micron

PM < 10 micron

Propylene oxide

Sulfur Dioxide

Toluene

Volatile Organic Compoun..

Xylenes, Total 0.09052.970.1840.790.0419.349.340.0189.342.8

236.30.163

0.09052.970.1840.790.0419.349.340.0189.342.8

683.30.163

0.02070.680.0420.2

0.009372.132.13

0.00412.130.6478

0.0371

PTE by subject item



Subject ItemCategoryDescription

Subject Item TypeDescription Subject Item ID SI Designation and Description Relationship

Related SubjectItem ID % Flow

Related Subject ItemType Description

Start Date (RelatedSubject Item)

End Date (RelatedSubject Item)

EquipmentReciprocating ICEngine

EQUI1EU002Emergency Generator

sends to STRU2 100 Stack/Vent 7/14/1997 Null

Turbine EQUI2 EU001Gas Turbine

sends to STRU1 100 Stack/Vent 7/20/2017 Null

STRU9 100 Stack/Vent 7/20/2017 Null

SI - SI relationships



Subject ItemTypeDescription Subject Item ID SI Designation and Description Manufacturer Model

Max DesignCapacity

Max DesignCapacityUnits(numerator)

Max DesignCapacity Units(denominator) Material

ConstructionStart Date

OperationStart Date

ModificationDate

Turbine EQUI2EU001Gas Turbine

Cooper RollsCoberra6562

41426 horsepower hours Energy 8/22/1997 4/11/1998 Null

Emission Units 1


Details for:SI Category: NoneSI Type: Turbine

Subject Item TypeDescription Subject Item ID SI Designation and Description Manufacturer Model

Max DesignCapacity

Max DesignCapacity Units(numerator)

Max DesignCapacity Units(denominator) Material

ConstructionStart Date

OperationStart Date

ModificationDate

Reciprocating IC EngineEQUI1EU002Emergency Generator

Waukesha F18GL 245 kilowatts hours Energy 8/22/1997 4/11/1998 Null

Emission Units 2


Details for:SI Category: EquipmentSI Type: Reciprocating IC Engine

Subject Item TypeDescription Subject Item ID SI Designation and Description

FiringMethod Engine Use

EngineDisplacement

EngineDisplacementUnits

Subject toCSAPR?

ElectricGeneratingCapacity(MW)

Reciprocating IC EngineEQUI1EU002Emergency Generator

SI-4SLB Emergency/blackstart 17960.2total cubiccentimeters

Null Null

Emission Units 2 (continued)


Details for:SI Category: EquipmentSI Type: Reciprocating IC Engine

Subject ItemTypeDescription Subject Item ID SI Designation and Description Height

Units(height) Length

Units(length) Width

Units(width)

Building STRU3BG001Compressor Building

42 feet 65 feet 60 feet

STRU4BG002Auxiliary Building


STRU5BG003Fuel Gas Utility Building


STRU6BG004Microwave Building



18 feet 130.5 feet 43 feet

STRU8NullValve Shelter

13 feet 10.2 feet 12.2 feet

Buildings, General


Details for:SI Category: StructureSI Type: Building

Subject ItemTypeDescription Subject Item ID SI Designation and Description

Stack Height(feet)

StackDiameter(feet)

Stack Length(feet)

Stack Width(feet)

Stack Flow Rate(cubic ft/min)

DischargeTemperature(°F)

Flow Rate/TempInformationSource Discharge Direction

Stack/Vent STRU1SV001Turbine

55 Null 9.5 11 438193 737 ManufacturerUpwards with no cap onstack/vent

STRU2SV002Emergency Generator

17 0.67 Null Null 2095 800 ManufacturerUpwards with a cap onstack/vent

STRU9NullWHOH

60 9.52 Null Null 262466 257 ManufacturerUpwards with a cap onstack/vent

Stack/Vent, General


Details for:SI Category: StructureSI Type: Stack/Vent

Subject Item ID Seq. # Requirement Citation

TFAC 1

(08300056) 2

Permit Appendices: This permit contains appendices as listed in the permit Table of Contents. The

Permi ee shall comply with all applicable requirements contained in Appendices A, C, and D.

Modeling parameters in Appendix B Modeled Parameters are included for reference only as

described elsewhere in this permit. Minn. R. 7007.0800, subp. 2

TFAC 1

(08300056) 3

PERMIT SHIELD: Subject to the limitations in Minn. R. 7007.1800, compliance with the conditions of

this permit shall be deemed compliance with the specific provision of the applicable requirement

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

7007.1800 and 7017.0100, subp. 2, notwithstanding the conditions of this permit specifying

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

use other credible evidence to establish compliance or noncompliance with applicable

requirements.

This permit shall not alter or affect the liability of the Permittee for any violation of applicable

requirements prior to or at the time of permit issuance. Minn. R. 7007.1800, (A)(2)

TFAC 1

(08300056) 7

The Permittee shall comply with National Primary and Secondary Ambient Air Quality Standards, 40

CFR pt. 50, and the Minnesota Ambient Air Quality Standards, Minn. R. 7009.0010 to 7009.0090.

Compliance shall be demonstrated upon written request by the MPCA.

Minn. R. 7007.0100, subp.

7(A), 7(L), & 7(M), Minn. R.

7007.0800, subp. 4, Minn. R.

7007.0800, subps. 1‐2, Minn.

Stat. 116.07, subd. 4a, Minn.

Stat. 116.07, subd. 9

TFAC 1

(08300056) 8

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

would otherwise violate a federal or state air pollution control rule, without reducing the total

amount of pollutant emitted. Minn. R. 7011.0020

TFAC 1

(08300056) 10

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

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

pollution control equipment and control practices and shall include a preventative maintenance

program for the equipment and practices, a description of (the minimum but not necessarily the

only) corrective actions to be taken to restore the equipment and practices to proper operation to

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

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

demonstrate plan implementation.

Minn. R. 7007.0800, subp. 14,

Minn. R. 7007.0800, subp.

16(J)

TFAC 1

(08300056) 11

Operation Changes: In any shutdown, breakdown, or deviation the Permittee shall immediately

take all practical steps to modify operations to reduce the emission of any regulated air pollutant.

The Commissioner may require feasible and practical modifications in the operation to reduce

emissions of air pollutants. No emissions units that have an unreasonable shutdown or breakdown

frequency of process or control equipment shall be permitted to operate. Minn. R. 7019.1000, subp. 4

TFAC 1

(08300056) 12

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

material in a manner which may allow avoidable amounts of particulate matter to become

airborne. Comply with all other requirements listed in Minn. R. 7011.0150. Minn. R. 7011.0150

TFAC 1

(08300056) 13

Noise: The Permittee shall comply with the noise standards set forth in Minn. R. 7030.0010 to

7030.0080 at all times during the operation of any emission units. This is a state only requirement

and is not enforceable by the EPA Administrator or citizens under the Clean Air Act. Minn. R. 7030.0010‐7030.0080

TFAC 1

(08300056) 14

Inspections: The Permittee shall comply with the inspection procedures and requirements as found

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

TFAC 1

(08300056) 15 The Permittee shall comply with the General Conditions listed in Minn. R. 7007.0800, subp. 16. Minn. R. 7007.0800, subp. 16

TFAC 1

(08300056) 16

Performance Testing: Conduct all performance tests in accordance with Minn. R. ch. 7017 unless

otherwise noted in this permit. Minn. R. ch. 7017

TFAC 1

(08300056) 17

Performance Test No fica ons and Submi als:

Performance Test No fica on and Plan: due 30 days before each Performance Test

Performance Test Pre‐test Mee ng: due 7 days before each Performance Test

Performance Test Report: due 45 days a er each Performance Test

The Notification, Test Plan, and Test Report must be submitted in a format specified by the

commissioner.

Minn. R. 7017.2017, Minn. R.

7017.2030, subps. 1‐4, Minn.

R. 7017.2035, subps. 1‐2


TFAC 1

(08300056) 18

Limits set as a result of a performance test (conducted before or after permit issuance) apply until

superseded as stated in the MPCA's Notice of Compliance letter granting preliminary approval.

Preliminary approval is based on formal review of a subsequent performance test on the same unit

as specified by Minn. R. 7017.2025, subp. 3. The limit is final upon issuance of a permit amendment

incorporating the change. Minn. R. 7017.2025, subp. 3

TFAC 1

(08300056) 19

Monitoring Equipment Calibra on ‐ The Permi ee shall either:

1. Calibrate or replace required monitoring equipment every 12 months; or

2. Calibrate at the frequency stated in the manufacturer's specifica ons.

For each monitor, the Permittee shall maintain a record of all calibrations, including the date

conducted, and any corrective action that resulted. The Permittee shall include the calibration

frequencies, procedures, and manufacturer's specifications (if applicable) in the Operations and

Maintenance Plan. Any requirements applying to continuous emission monitors are listed

separately in this permit. Minn. R. 7007.0800, subp. 4(D)

TFAC 1

(08300056) 20

Operation of Monitoring Equipment: Unless noted elsewhere in this permit, monitoring a process or

control equipment connected to that process is not necessary during periods when the process is

shutdown, or during checks of the monitoring systems, such as calibration checks and zero and span

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

shutdown or checks of the monitoring system. Minn. R. 7007.0800, subp. 4(D)

TFAC 1

(08300056) 21

Nitrogen Dioxide: The Permittee shall submit a computer dispersion modeling protocol due 1096

calendar days after Permit Issuance Date, for 1‐hour Nitrogen Dioxide. This protocol will describe

the proposed modeling methodology and input data, in accordance with MPCA modeling guidance

for Title V air dispersion modeling analyses. The protocol will be based on projected operating

conditions under the next permit term.

Minn. R. 7007.0100, Minn. R.

7007.0800, subp. 2, Minn. R.

7009.0020, Minn. Stat. 116.07,

subd. 4a, Minn. Stat. 116.07,

subd. 9

TFAC 1

(08300056) 22

Nitrogen Dioxide: The Permittee shall submit computer dispersion modeling results due 1461

calendar days after Permit Issuance Date.

Minn. R. 7007.0100, Minn. R.

7007.0800, subp. 2, Minn. R.

7009.0020, Minn. Stat. 116.07,

subd. 4a, Minn. Stat. 116.07,

subd. 9

TFAC 1

(08300056) 25

The Permittee shall submit an application for permit reissuance : Due 180 calendar days before

Permit Expiration Date. Minn. R. 7007.0400, subp. 2

TFAC 1

(08300056) 26

Recordkeeping: Retain all records at the stationary source, unless otherwise specified within this

permit, for a period of five (5) years from the date of monitoring, sample, measurement, or report.

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

original recordings for continuous monitoring instrumentation, and copies of all reports required by

the permit. Records must conform to the requirements listed in Minn. R. 7007.0800, subp. 5(A). Minn. R. 7007.0800, subp. 5(C)

TFAC 1

(08300056) 27

Recordkeeping: Maintain records describing any insignificant modifications (as required by Minn. R.

7007.1250, subp. 3) or changes contravening permit terms (as required by Minn. R. 7007.1350,

subp. 2), including records of the emissions resulting from those changes. Minn. R. 7007.0800, subp. 5(B)

TFAC 1

(08300056) 28

If the Permittee determines that no permit amendment or notification is required prior to making a

change, the Permittee must retain records of all calculations required under Minn. R. 7007.1200.

These records shall be kept for a period of five years from the date the change was made or until

permit reissuance, whichever is longer. The records shall be kept at the stationary source for the

current calendar year of operation and may be kept at the stationary source or office of the

stationary source for all other years. The records may be maintained in either electronic or paper

format. Minn. R. 7007.1200, subp. 4

TFAC 1

(08300056) 29

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

shutdown of any control equipment or process equipment if the shutdown would cause any

increase in the emissions of any regulated air pollutant. If the owner or operator does not have

advance knowledge of the shutdown, notification shall be made to the Commissioner as soon as

possible after the shutdown. However, notification is not required in the circumstances outlined in

Items A, B and C of Minn. R. 7019.1000, subp. 3.

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

shutdown and the estimated duration. The owner or operator shall notify the Commissioner when

the shutdown is over. Minn. R. 7019.1000, subp. 3


TFAC 1

(08300056) 30

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

one hour duration of any control equipment or process equipment if the breakdown causes any

increase in the emissions of any regulated air pollutant. The 24‐hour time period starts when the

breakdown was discovered or reasonably should have been discovered by the owner or operator.

However, notification is not required in the circumstances outlined in Items A, B and C of Minn. R.

7019.1000, subp. 2.

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

Commissioner of the cause of the breakdown and the estimated duration. The owner or operator

shall notify the Commissioner when the breakdown is over. Minn. R. 7019.1000, subp. 2

TFAC 1

(08300056) 31

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

discovery, notify the Commissioner or the state duty officer, either orally or by facsimile, of any

deviation from permit conditions which could endanger human health or the environment. Minn. R. 7019.1000, subp. 1

TFAC 1

(08300056) 32

Notification of Deviations Endangering Human Health or the Environment Report: Within 2 working

days of discovery, notify the Commissioner in writing of any deviation from permit conditions which

could endanger human health or the environment. Include the following information in this written

descrip on:

1. the cause of the devia on;

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

3. whether or not the devia on has been corrected;

4. the an cipated me by which the devia on is expected to be corrected, if not yet corrected; and

5. steps taken or planned to reduce, eliminate, and prevent reoccurrence of the deviation. Minn. R. 7019.1000, subp. 1

TFAC 1

(08300056) 33

The Permittee shall submit a semiannual deviations report : Due semiannually, by the 30th of

January and July The first semiannual report submitted by the Permittee shall cover the calendar

half‐year in which the permit is issued. The first report of each calendar year covers January 1 ‐ June

30. The second report of each calendar year covers July 1 ‐ December 31. If no deviations have

occurred, the Permittee shall submit the report stating no deviations.

Minn. R. 7007.0800, subp.

6(A)(2)

TFAC 1

(08300056) 35

Application for Permit Amendment: If a permit amendment is needed, submit an application in

accordance with the requirements of Minn. R. 7007.1150 through Minn. R. 7007.1500. Submittal

dates vary, depending on the type of amendment needed.

Upon adoption of a new or amended federal applicable requirement, and if there are more than 3

years remaining in the permit term, the Permittee shall file an application for an amendment within

nine months of promulgation of the applicable requirement, pursuant to Minn. R. 7007.0400, subp.

3.

Minn. R. 7007.0400, subp. 3,

Minn. R. 7007.1150 ‐

7007.1500

TFAC 1

(08300056) 36

Extension Requests: The Permittee may apply for an Administrative Amendment to extend a

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

the requirements of Minn. R. 7007.1400, subp. 1(H). Performance testing deadlines from the

General Provisions of 40 CFR pt. 60 and pt. 63 are examples of deadlines for which the MPCA does

not have authority to grant extensions and therefore do not meet the requirements of Minn. R.

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

TFAC 1

(08300056) 38

The Permittee shall submit a compliance certification : Due annually, by the 31st of January (for the

previous calendar year). The Permittee shall submit this to the Commissioner on a form approved

by the Commissioner. This report covers all deviations experienced during the calendar year. Minn. R. 7007.0800, subp. 6(C)

TFAC 1

(08300056) 39

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

issuance. Submit in a format specified by the Commissioner. Minn. R. 7019.3000‐7019.3100

TFAC 1

(08300056) 40 Emission Fees: due 30 days after receipt of an MPCA bill. Minn. R. 7002.0005‐7002.0095

TFAC 1

(08300056) 42

Modeled Parameters for Nitrogen Dioxide: The parameters used in nitrogen dioxide modeling

(February 2009) are listed in Appendix B of this permit. The parameters describe the operation of

the facility at maximum permitted capacity. The purpose of listing the parameters in the appendix is

to provide a benchmark for future changes.

Minn. R. 7007.0100, subp.

7(A), 7(L), & 7(M), Minn. R.

7007.0800, subp. 4, Minn. R.

7007.0800, subps. 1‐2, Minn.

R. 7009.0010‐7009.0090,

Minn. Stat. 116.07, subd. 4a,

Minn. Stat. 116.07, subd. 9


TFAC 1

(08300056) 43

The Permittee shall not use engines that meet section (1)(iii) under the definition of Nonroad

Engine at 40 CFR Section 1068.30 in one location within the stationary source for more than 12

consecu ve months. A loca on is any single site at a building, structure, facility, or installa on.

Any engine, or engines, that replaces an engine at a location and that is intended to perform the

same or similar function as the engine it replaced will be included in calculating the consecutive

time period. 40 CFR 1068.30

TFAC 1

(08300056) 44

For a nonroad engine that is excluded from any requirements of 40 CFR Part 1068 because it is a

stationary engine, the Permittee may not move it or install it in any mobile equipment, except as

allowed by the provisions of 40 CFR Part 1068. The Permittee may not circumvent or attempt to

circumvent the residence‐time requirements of Section (2)(iii) of the Nonroad Engine definition at

40 CFR Section 1068.30. 40 CFR 1068.101(b)(3)

TFAC 1

(08300056) 45

The Permittee shall conduct an inventory of all engines on‐site that meet section (1)(iii) under the

definition of Nonroad Engine at 40 CFR Section 1068.30, once each calendar quarter; inventories

shall not take place in consecutive months. This applies to nonroad engines that are owned by the

Permittee, or rented and operated by the Permittee, or brought onsite and operated by a vendor or

contractor. The inventory shall include the following:

1) Date that the nonroad engine is inventoried.

2) Iden fica on number.

3) Func on of the nonroad engine (e.g. compressor, welder).

4) Loca on of the engine within the sta onary source.

5) Statement that the nonroad engine has not been located and used in a single location for 12

consecutive months, and movement between locations has not been for purposes of circumvention

of residence time requirements of section (2)(iii) under the definition of Nonroad Engine at 40 CFR

Section 1068.30.

40 CFR 1068.30(nonrd

engn)(1)(iii), Minn. R.

7007.0800, subps. 4‐5

TFAC 1

(08300056) 46

A nonroad engine ceases to be a nonroad engine and becomes a new sta onary engine if:

1. At any time, it meets the criteria specified in section (2)(iii) under the definition of Nonroad

Engine in 40 CFR Section 1068.30. For example, a portable generator engine ceases to be a nonroad

engine if it is used or will be used in a single specific location for 12 months or longer. If the

Administrator or the Permitting authority determines that an engine will be or has been used in a

single specific location for 12 months or longer, it ceased to be a nonroad engine when it was

placed in that loca on.

OR

2. It is otherwise regulated by a federal New Source Performance Standard promulgated under

section 111 of the Clean Air Act (42 U.S.C. 7411). 40 CFR 1068.31(e)

EQUI 1

(EU002) 1

a. Change oil and filter every 500 hours of opera on or annually, whichever comes first;

b. Inspect spark plugs every 1,000 hours of operation or annually, whichever comes first, and

replace as necessary; and

c. Inspect all hoses and belts every 500 hours of operation or annually, whichever comes first, and

replace as necessary.

40 CFR 63.6603(a), Minn. R.

7011.8150

EQUI 1

(EU002) 4

The Permittee must comply with the applicable requirements of 40 CFR pt. 63, subp. ZZZZ, as

follows:

40 CFR Sec on 63.6580;

40 CFR Sec on 63.6585(a);

40 CFR Sec on 63.6585(c);

40 CFR Sec on 63.6590 (a)(1)(iii);

40 CFR Sec on 63.6595(a)(1);

40 CFR Sec on 63.6603(a);

40 CFR Sec on 63.6605(a);

40 CFR Sec on 63.6605(b);

40 CFR Sec on 63.6625(e)(3);


40 CFR Section 63.6625(f);

40 CFR Section 63.6625(h);

40 CFR Section 63.6625(j);

40 CFR Section 63.6640(f)(1);

40 CFR Section 63.6640(f)(2)(i);

40 CFR Section 63.6640(f)(4);

40 CFR Section 63.6645(a)(5);

40 CFR Section 63.6655(e)(2);

40 CFR Section 63.6655(f)(2);

40 CFR Section 63.6660(a);

40 CFR Section 63.6660(b);

40 CFR Section 63.6660(c);

40 CFR Section 63.6665;

40 CFR Section 63.6675;

40 CFR pt. 63, subp. ZZZZ, Table 2d, item 5;

40 CFR pt. 63, subp. ZZZZ, Table 6, item 9;

40 CFR pt. 63, subp. ZZZZ, Table 8.

A copy of 40 CFR pt. 63, subp. ZZZZ is in Appendix C.

If the standard changes or upon adoption of a new or amended federal applicable requirement, and

if there are more than 3 years remaining in the permit term, the Permittee shall file an application

for an amendment within nine months of promulgation of the applicable requirement, pursuant to

Minn. R. 7007.0400, subp. 3.

40 CFR 63.subp. ZZZZ, Minn. R.

7007.0400, subp. 3, Minn. R.

7007.1150‐1500, Minn. R.

7011.8150

EQUI 1

(EU002) 5

The Permi ee must comply with all applicable requirements of 40 CFR pt. 63, subp. A as follows:

40 CFR 63.1;

40 CFR 63.2;

40 CFR 63.3;

40 CFR 63.4;

40 CFR 63.5;

40 CFR 63.6(a)(1);

40 CFR 63.6(a)(2);

40 CFR 63.6(c)(1);

40 CFR 63.6(c)(2);

40 CFR 63.6(c)(5);

40 CFR 63.6(f)(2);

40 CFR 63.6(f)(3);

40 CFR 63.6(g);

40 CFR 63.6(i);

40 CFR 63.6(j);

40 CFR 63.7(a)(2)(ix);

40 CFR 63.7(a)(3);

40 CFR 63.7(a)(4);

40 CFR 63.7(b);

40 CFR 63.7(c);

40 CFR 63.7(d);

40 CFR 63.7(e);


40 CFR 63.7(f);

40 CFR 63.7(g);

40 CFR 63.7(h);

40 CFR 63.8(a)(1);

40 CFR 63.8(a)(2);

40 CFR 63.8(b)(1);

40 CFR 63.8(b)(2);

40 CFR 63.8(b)(3);

40 CFR 63.8(c)(1)(ii);

40 CFR 63.8(c)(2);

40 CFR 63.8(c)(3);

40 CFR 63.8(c)(6);

40 CFR 63.8(c)(7);

40 CFR 63.8(c)(8);

40CFR 63.8(e)(1);

40 CFR 63.8(e)(2);

40 CFR 63.8(e)(3);

40 CFR 63.8(e)(5)(i)

40 CFR 63.8(f);

40 CFR 63.8(g);

40 CFR 63.9(b);

40 CFR 63.9(c);

40 CFR 63.9(d);

40 CFR 63.9(e);

40 CFR 63.10(a)(5);

40 CFR 63.10(a)(6);

40 CFR 63.10(a)(7);

40 CFR 63.10(b)(1);

40 CFR 63.10(b)(2)(vi)‐(xii);

40 CFR 63.10(b)(2)(xiv);

40 CFR 63.10(b)(3);

40 CFR 63.10(c);

40 CFR 63.10(d)(1);

40 CFR 63.10(d)(2);

40 CFR 63.10(d)(4);

40 CFR 63.10(e)(1);

40 CFR 63.10(e)(2)(i);

40 CFR 63.10(f);

40 CFR 63.12;

40 CFR 63.13;

40 CFR 63.14;

40 CFR 63.15

A copy of 40 CFR pt. 63, subp. A is included in Appendix D. If the standard changes or upon adoption

of a new or amended federal applicable requirement, and if there are more than 3 years remaining

in the permit term, the Permittee shall file an application for an amendment within nine months of

promulgation of the applicable requirement, pursuant to Minn. R. 7007.0400, subp. 3.

40 CFR 63.6665, 40 CFR pt. 63,

subp. A, 40 CFR pt. 63, subp.

ZZZZ(Table 8), Minn. R.

7007.0400, subp. 3, Minn. R.

7007.1150‐1500, Minn. R.

7011.7000, Minn. R.

7011.8150, Minn. R. 7017.1010

& 7017.2025, Minn. R.

7019.0100

EQUI 1

(EU002) 6 Opacity <= 20 percent opacity once operating temperatures have been attained. Minn. R. 7011.2300, subp. 1

EQUI 1

(EU002) 7

Sulfur Dioxide <= 0.50 pounds per million Btu heat input. The potential to emit from the unit is

0.0006 lb/MMBtu due to equipment design and allowable fuels. Minn. R. 7011.2300, subp. 2(A)

EQUI 1

(EU002) 8

Sulfur Dioxide <= 0.0015 pounds per million Btu heat input. This limit is effective on January 31,

2018. The potential to emit from the unit is 0.0006 lb SO2 per MMBtu due to equipment design and

allowable fuels. Minn. R. 7011.2300, subp. 2(B)

EQUI 1

(EU002) 9 Fuel type: Natural gas only by design. Minn. R. 7005.0100, subp. 35a

EQUI 1

(EU002) 10

Hours of Operation: The Permittee shall maintain documentation on site that the unit is an

emergency generator by design that qualifies under the U.S. EPA memorandum entitled

"Calculating Potential to Emit (PTE) for Emergency Generators" dated September 6, 1995, limiting

operation to 500 hours per year. Minn. R. 7007.0800, subps. 4‐5

EQUI 1

(EU002) 11 The Permittee shall keep records of fuel type and usage on a monthly basis. Minn. R. 7007.0800, subp. 5


EQUI 2

(EU001) 1 Nitrogen Oxides <= 52.5 pounds per hour during DLE operation.

40 CFR 60.332(a)(2), Minn. R.

7011.2350, Title I Condition:

Avoid major source under 40

CFR 52.21(b)(1)(i) and Minn. R.

7007.3000

EQUI 2

(EU001) 2 Nitrogen Oxides <= 0.0217 percent by volume at 15 percent oxygen and on a dry basis.

40 CFR 60.332(a)(2), Minn. R.

7011.2350

EQUI 2

(EU001) 3 Nitrogen Oxides <= 78 pounds per hour during non‐DLE operation.

40 CFR 60.332(a)(2), Minn. R.




7007.3000

EQUI 2

(EU001) 7 Sulfur Dioxide <= 0.015 percent by volume at 15 percent oxygen and on a dry basis.

40 CFR 60.333, Minn. R.

7011.2350

EQUI 2

(EU001) 8

Sulfur Dioxide <= 0.50 pounds per million Btu heat input. The potential to emit from the unit is

0.0006 lb/MMBtu due to equipment design and allowable fuels. Minn. R. 7011.2300, subp. 2(A)

EQUI 2

(EU001) 9

Sulfur Dioxide <= 0.0015 pounds per million Btu heat input. This limit is effective on January 31,

2018. The potential to emit from the unit is 0.0006 lb SO2 per MMBtu due to equipment design and

allowable fuels. Minn. R. 7011.2300, subp. 2(B)

EQUI 2

(EU001) 10 Opacity <= 20 percent opacity once operating temperatures have been attained. Minn. R. 7011.2300, subp. 1

EQUI 2

(EU001) 11 Fuel type: Natural gas only by design. Minn. R. 7005.0100, subp. 35a

EQUI 2

(EU001) 12 Fuel Type: Limited to pipeline natural gas meeting the definition in 40 CFR Section 60.331(u). Minn. R. 7007.0800, subp. 2

EQUI 2

(EU001) 13 Sulfur Content of Fuel <= 0.8 percent by weight.

40 CFR 60.333, Minn. R.

7011.2350

EQUI 2

(EU001) 14

Fuel Monitoring: The Permittee shall follow the applicable fuel sulfur content monitoring

requirements in 40 CFR Section 60.334(h) and shall monitor at the frequency specified in 40 CFR

Sec on 60.334(i).

40 CFR Section 60.334(h)(3) allows the Permittee to not monitor total sulfur content of gaseous fuel

if the fuel is shown to meet the definition of natural gas as defined in 40 CFR Section 60.331(u).

40 CFR 60.334(h)‐(i), Minn. R.

7011.2350

EQUI 2

(EU001) 15 The Permittee shall keep records of fuel type and usage on a monthly basis. Minn. R. 7007.0800, subp. 5

EQUI 2

(EU001) 16

Operation in non‐DLE mode limited to 500 hours per 12‐month period based on a 12‐month rolling

sum.

Title I Condition: Avoid major

source under 40 CFR

52.21(b)(1)(i) and Minn. R.

7007.3000

EQUI 2

(EU001) 17

Daily Recordkeeping: On each day of operation in non‐DLE mode, the Permittee shall calculate,

record, and maintain a record of the total hours of operation in non‐DLE mode. This shall be based

on written logs or hour meter readings.


source under 40 CFR

52.21(b)(1)(i) and Minn. R.

7007.3000

EQUI 2

(EU001) 18

Monthly Recordkeeping:

By the 15th of the month, the Permi ee shall calculate and record the following:

1) The total hours of operation in non‐DLE mode for the previous calendar month, using the daily

records; and

2) The 12‐month rolling sum hours of operation in non‐DLE mode for the previous 12‐month period

by summing the monthly hours of operation for the previous 12 months. Minn. R. 7007.0800, subps. 4‐5


EQUI 2

(EU001) 26

Gas Turbine Replacement and Reconstruction: The gas turbine is composed of four main

components: an axial compressor, combustor, high pressure turbine (provides mechanical power to

drive the axial compressor), and the power turbine (converts thermal to mechanical energy to drive

the pipeline compressor). The axial compressor, combustor and high pressure turbine are also

known as a gas generator. The gas generator is a RB211‐24G DLE and the power turbine is

manufactured by Cooper Rolls.

The Permittee is authorized to replace any or all of the four components for maintenance purposes

at manufacturer's specified time intervals as specified later in this permit. Replacement of

components meeting the definition of 'reconstruction' as defined at 40 CFR Section 60.15, triggers

requirements of 40 CFR pt. 60, subp. KKKK for reconstructed facilities. This permit includes the 40

CFR pt. 60, subp. KKKK requirements for reconstructed affected facili es.

If 40 CFR pt. 60, subp. KKKK (subp. KKKK) requirements are triggered due to reconstruction, the

Permittee is no longer subject to 40 CFR pt. 60, subp. GG (subp. GG), and shall meet the subp. KKKK

requirements in this subject item. Minn. R. 7007.0800, subp. 2

EQUI 2

(EU001) 27

EQUI 2 Turbine Component Replacement Authorization: The Permittee may make the replacements

specified below without the need for a permit amendment if there is no increase in the hourly

emissions rate, no new applicable requirements are triggered, and the Permittee continues to

comply with all exis ng applicable permit condi ons.

The Permittee is allowed to replace any of the four main gas turbine components (defined earlier in

this permit) with similar components as needed. The Permittee may also replace the entire gas

generator (axial compressor, combustor, and high pressure turbine) with a gas generator of the

same model and ISO‐rated horsepower. If replacement of components qualifies EQUI 2 as a

reconstructed facility for purposes of subp. KKKK, the Permittee shall follow the applicable subp.

KKKK requirements in this subject item (those designated as Reconstructed Units) instead of the

subp. GG requirements.

The Permittee is not authorized to install an additional gas turbine, is not authorized to completely

replace the entire stationary gas turbine as defined at 40 CFR Section 60.4420, is not permitted to

operate more than one turbine at the facility, and is not authorized to increase the emission rate

(lb/hr, tpy, lb/hp‐hr, lb/mmBtu, etc.) of any pollutant with this authoriza on.

The gas turbine will continue to be designated as EQUI 2 regardless if these components have been

replaced, and the gas turbine shall continue to be subject to all applicable requirements listed

under subject item EQUI 2.


modification under 40 CFR

52.21(b)(2) and Minn. R.




7007.3000

EQUI 2

(EU001) 28

Turbine Component Replacement Recordkeeping: The Permittee shall record the date and nature of

each component replacement no later than 5 business days a er comple on of each replacement.

The Permittee shall also record the total cost of the component replacement compared to the cost

of an entirely new stationary gas turbine (as defined at 40 CFR Section 60.4420). This record shall be

made at least 30 days before a NOx test is conducted on the gas turbine (as a result of the

component replacement), but no later than 180 days after each component replacement.

Minn. R. 7007.0800, subp. 2,

Minn. R. 7007.0800, subp. 4,

Minn. R. 7007.0800, subp. 5

EQUI 2

(EU001) 4550

The Permittee shall submit a notification of date reconstruction began: Due 30 calendar days after

Date of Construction Start (or reconstruction). Submit the name and number of the Subject Item

and the date construction began.

40 CFR 60.7(a)(1), Minn. R.

7019.0100, subp. 1

EQUI 2

(EU001) 4560

The Permittee shall submit a notification of the actual date of initial startup of the reconstructed

EQUI 2: Due 15 calendar days after Initial Startup Date.

40 CFR 60.7(a)(3), Minn. R.

7019.0100, subp. 1

EQUI 2

(EU001) 4590

The Permittee shall submit notification of the anticipated date reconstruction is to begin: Due 60

calendar days before Date of Construction or Reconstruction (or as soon as practicable). Submit the

information specified in 40 CFR Section 60.15(d)(1) through (7).

40 CFR 60.15(d), Minn. R.

7011.0050

EQUI 2

(EU001) 6380

Reconstructed Units:

The Permittee shall limit emissions of Sulfur Dioxide <= 110 nanograms per joule (0.90 lb/MWh)

gross output or the Permittee must not burn any fuel in EQUI 2 which contains total potential sulfur

emissions in excess of 26 ng SO2/J (0.060 lb SO2/MMBtu) heat input.

40 CFR 60.4330(a), Minn. R.

7011.2375


EQUI 2

(EU001) 6390


The Permittee shall limit emissions of Nitrogen Oxides <= 42 parts per million at 15 percent O2 or

250 ng/J of useful output (2.0 lb/MWh) when turbine is operating at or above 75 percent of peak

load and when operating at 0 deg F or above.

40 CFR 60.4320(a), Minn. R.

7011.2375

EQUI 2

(EU001) 6400


The Permittee shall limit emissions of Nitrogen Oxides <= 150 parts per million at 15 percent O2 or

1,100 ng/J of useful output (8.7 lb/MWh) when turbine is operating at less than 75 percent of peak

load or operating at temperatures less than 0 deg F.

40 CFR 60.4320(a), Minn. R.

7011.2375

EQUI 2

(EU001) 6410


The Permittee must operate and maintain the turbine, air pollution control equipment, and

monitoring equipment in a manner consistent with good air pollution control practices for

minimizing emissions at all times including startup, shutdown, and malfunction.

40 CFR 60.4333(a), Minn. R.

7011.2375

EQUI 2

(EU001) 6420


As an alternative to 40 CFR Section 60.4340(a) performance testing requirements, the Permittee

may install, calibrate, maintain and operate one of the following con nuous monitoring systems:

(1) Con nuous emission monitoring as described in Sec ons 60.4335(b) and 60.4345, or

(2) Con nuous parameter monitoring as follows:

(ii) For any lean premix stationary combustion turbine, the Permittee must continuously monitor

the appropriate parameters to determine whether the unit is opera ng in low‐NOx mode.

If any of these options are chosen, the Permittee shall comply with all applicable portions of 40 CFR

pt. 60, subp. KKKK, and the Permittee shall apply for a permit amendment as applicable to

incorporate such requirements.

40 CFR 60.4340(b), Minn. R.

7011.2375

EQUI 2

(EU001) 6430


Fuel Sulfur Content: The Permittee shall maintain a current valid purchase contract, tariff sheet, or

transportation contract for the fuel, specifying the maximum total sulfur content for natural gas is

20 grains of sulfur or less per 100 standard cubic feet.

40 CFR 60.4365(a), Minn. R.

7011.2375

EQUI 2

(EU001) 6440


The Permittee shall perform annual performance tests in accordance with 40 CFR Section 60.4400

to demonstrate continuous compliance. If the NOx emission result from the performance test is less

than or equal to 75 percent of the NOx emission limit in 40 CFR 60.4320(a) for the turbine, the

Permittee may reduce the frequency of subsequent performance tests to once every 2 years (no

more than 26 calendar months following the previous performance test). If the results of any

subsequent performance test exceed 75 percent of the NOx emission limit for the turbine, the

Permittee must resume annual performance tests.

40 CFR 60.4340(a), Minn. R.

7011.2375

EQUI 2

(EU001) 6450


Initial Performance Test: due 180 days after Initial Startup and reconstruction of EQUI 2, for NOx in

accordance with 40 CFR Sections 60.8 and 60.4400.

40 CFR 60.4400, 40 CFR

60.8(a), Minn. R. 7011.2375,

Minn. R. 7017.2020, subp. 1

EQUI 2

(EU001) 6470


NOx Performance Test Report: In addition to the other notifications and submittals required by

Minn. R. ch. 7017, the Permittee shall submit a written report of the results of each NOx

performance test before the close of business on the 60th day following completion of the

performance test.

40 CFR 60.4375(b), Minn. R.

7011.2375

EQUI 2

(EU001) 19000

The Permittee shall maintain records of the occurrence and duration of any startup, shutdown, or

malfunction in the operation of an affected facility; any malfunction of the air pollution control

equipment; or any periods during which a continuous monitoring system or monitoring device is

inoperative.

40 CFR 60.7(b), Minn. R.

7019.0100, subp. 1

EQUI 2

(EU001) 19010

The Permittee shall maintain a file of all measurements, including continuous monitoring system,

monitoring device, and performance testing measurements; all continuous monitoring system

performance evaluations; all continuous monitoring system or monitoring device calibration checks;

adjustments and maintenance performed on these systems or devices; and all other information

required by 40 CFR pt. 60 recorded in a permanent form suitable for inspection. The file shall be

retained for at least two years following the date of such measurements, maintenance, reports, and

records, except as specified in 40 CFR Section 60.7(f)(1)‐(3).

40 CFR 60.7(f), Minn. R.

7019.0100, subp. 1


EQUI 2

(EU001) 19021

Nitrogen Oxides: The Permittee shall conduct a performance test due 90 days after replacing

components as allowed for EQUI 2, to measure emissions. The performance test shall be conducted

at worst‐case conditions as defined at Minn. R. 7017.2025, subp. 2, using EPA Reference Method

7E, or other method approved by MPCA in the performance test plan approval. Testing shall be

done for both DLE and non‐DLE modes.

Minn. R. 7017.2020, subp. 1,


source under 40 CFR

52.21(b)(1)(i) and Minn. R.

7007.3000

Attachment 3 – Custom NOX monitoring plan

Attachment 4 – Excerpts from Modeling Results Document

NORTHERN BORDER PIPELINE COMPANY COMPRESSOR STATION NO. 12 LYON COUNTY, MINNESOTA

AIR QUALITY DISPERSION MODELING ANALYSIS

EMA Report No. 2063-01

February 2009

Prepared for:

Northern Border Pipeline Company 13710 FNB Parkway

Omaha, Nebraska 68154-5200

ENVIRONMENTAL MANAGEMENT ASSOCIATES

i 2063 CS12 Air Model Report V02.docx

NORTHERN BORDER PIPELINE COMPANY COMPRESSOR STATION NO. 12 LYON COUNTY, MINNESOTA

AIR QUALITY DISPERSION MODELING ANALYSIS

EMA Report No. 2063-01

February 2009

Prepared for:

Northern Border Pipeline Company 13710 FNB Parkway

Omaha, Nebraska 68154-5200

LIMITATIONS

This report was prepared by Environmental Management Associates, Inc. (EMA) in conformance with the scope of work prescribed by our client. The work has been conducted in an objective and unbiased manner and in accordance with generally accepted professional practice for this type of work. No other warranty, either expressed or implied, is made as to the findings, recommendations, specifications, or opinions expressed herein.

ENVIRONMENTAL MANAGEMENT ASSOCIATES, INC.

Dwight L. Carey, D.Env. Principal

Air Quality Dispersion Modeling Analysis Northern Border Pipeline Company Compressor Station No. 12 Lyon County, Minnesota

- 7 - 2063 CS12 Air Model Report V02.docx

4. RESULTS

4.1 AERMOD Model Results

One model run was conducted to evaluate the annual ambient NOX concentrations for each of the source groups for each of the five calendar years of meteorological data modeled, for a total of five model runs. Electronic copies of the input and output files for each model run are enclosed on the compact disk provided in APPENDIX B.

Table 2 lists the annual ambient NOX standard, the modeled high annual NOX concentration, the added “background” NOX concentration, and the location and modeled year for the five-year set of meteorological data modeled for each source group. Without the added background NOX concentration, the modeled annual five-year high NOX concentrations from the two turbine stacks are very low; under 2 µg/m3 NOX for the existing stack and less than 4 µg/m3 NOX for the WHOH stack. The modeled five-year annual NOX concentration highs for the OREG 2 and CS-12 emergency generator engines are higher; without the added background concentration, the modeled five-year high annual NOX concentration for the OREG 2 emergency generator engine is about 12 µg/m3, while the modeled five-year high annual NOX concentration for the CS-12 emergency generator engine is almost 40 µg/m3. Each modeled high annual NOX concentrations for each modeled year for each individual source group is located on one of the Facility property boundary receptors.

The modeled high annual NOX concentrations for the eight multiple-emission-source source groups are dominated by the contribution of the CS-12 emergency generator engine; the highest modeled five-year high annual NOX concentration for the combination of the WHOH stack and both the CS-12 and OREG 2 emergency generator engines is almost 42 µg/m3. However, even with the addition of the background annual NOX concentration of 17.0 µg/m3, the highest predicted five-year high NOX concentration was less than 60 µg/m3, which is well below the annual ambient NOX standard of 100 µg/m3. Because all of these modeled highest first high NOX concentrations were well below the annual ambient air quality standard, none were contoured or plotted.

Air Quality Dispersion Modeling Analysis Northern Border Pipeline Company Compressor Station No. 12 Lyon County, Minnesota

- 1 - 2063 CS12 Air Model Report V02.docx

Table 2: Summary of Modeled Maximum First High Annual Nitrogen Oxide Concentrations

NORTHERN BORDER PIPELINE CS-12 - MAXIMUM MODELED ANNUAL NITROGEN OXIDE CONCENTRATIONS - 1986-1990 - RS440960

Model ID Description Concentration (:g/m3) Total % of

Ambient Standard

Location (Zone 15 NAD83 UTM

meters) Year Ambient Standard

Modeled High Background Total Easting Northing

OLDST100 Currently Permitted Stack @ 100% Load 100 0.94 17.00 17.94 17.94% 278,551 4,901,756 1988 OLDST090 Currently Permitted Stack @ 90% Load 100 1.52 17.00 18.52 18.52% 278,551 4,901,756 1988 OLDST075 Currently Permitted Stack @ 75% Load 100 1.38 17.00 18.38 18.38% 278,551 4,901,756 1988 OLDST060 Currently Permitted Stack @ 60% Load 100 1.82 17.00 18.82 18.82% 278,551 4,901,756 1988 CS12GENH CS-12 Emergency Generator 8760 Hours 100 38.59 17.00 55.59 55.59% 278,526 4,901,757 1989

OREGEMRH OREG2 Emergency Generator 8760 Hours 100 11.71 17.00 28.71 28.71% 278,676 4,901,755 1990 WHOHC100 WHOH Capped Stack @ 100% Load 100 3.14 17.00 20.14 20.14% 278,647 4,901,444 1990 WHOHC090 WHOH Capped Stack @ 90% Load 100 3.39 17.00 20.39 20.39% 278,647 4,901,444 1990 WHOHC075 WHOH Capped Stack @ 75% Load 100 3.09 17.00 20.09 20.09% 278,647 4,901,444 1990 WHOHC060 WHOH Capped Stack @ 60% Load 100 3.56 17.00 20.56 20.56% 278,647 4,901,444 1990 OLDST10H OLDST100, CS12GENH, OREGEMRH 100 40.54 17.00 57.54 57.54% 278,551 4,901,756 1989 OLDST60H OLDST060, CS12GENH, OREGEMRH 100 41.12 17.00 58.12 58.12% 278,576 4,901,756 1990 OLDST75H OLDST075, CS12GENH, OREGEMRH 100 40.75 17.00 57.75 57.75% 278,551 4,901,756 1989 OLDST90H OLDST090, CS12GENH, OREGEMRH 100 40.80 17.00 57.80 57.80% 278,576 4,901,756 1990

WHOHC10H WHOHC100, CS12GENH, OREGEMRH 100 41.37 17.00 58.37 58.37% 278,576 4,901,756 1990 WHOHC60H WHOHC060, CS12GENH, OREGEMRH 100 41.65 17.00 58.65 58.65% 278,576 4,901,756 1990 WHOHC75H WHOHC075, CS12GENH, OREGEMRH 100 41.36 17.00 58.36 58.36% 278,576 4,901,756 1990 WHOHC90H WHOHC090, CS12GENH, OREGEMRH 100 41.49 17.00 58.49 58.49% 278,576 4,901,756 1990

APPENDIX C: MODELING EMISSION PARAMETERS

Vertical Stack Parameters

(feet) NOx Stack Height

Stack Gas Temperature

Stack Gas Velocity

Stack Diameter

Stack Gas Flow Rate

Easting Northing Elevation (lbs/hr)

(feet) (°F) (feet/sec) (feet) (actual cubic

OLDST100 Currently Permitted Stack @ 100% Load 278596.5 4901645.3 1530.8 52.50 55.00 737.0 69.887241 11.5349 438193.0OLDST090 Currently Permitted Stack @ 90% Load 278596.5 4901645.3 1530.8 52.50 55.00 653.0 60.072178 11.5349 376652.6OLDST075 Currently Permitted Stack @ 75% Load 278596.5 4901645.3 1530.8 47.86 55.00 653.0 60.072178 11.5349 376652.6OLDST060 Currently Permitted Stack @ 60% Load 278596 5 4901645 3 1530 8 43 73 55 00 617 0 52 460630 11 5349 328928 1

Model ID Description

Vertical Stack Source Modeling ParametersUTM Zone 15 (meters

- NAD83)

OLDST060 Currently Permitted Stack @ 60% Load 278596.5 4901645.3 1530.8 43.73 55.00 617.0 52.460630 11.5349 328928.1CS12GENH CS-12 Emergency Generator 8760 Hours 278551.7 4901650.1 1532.3 14.12 17.00 800.0 100.0000 0.6667 2094.4OREGEMRH OREG2 Emergency Generator 8760 Hours 278658.9 4901694.8 1532.8 1.51 16.00 800.0 94.3895 0.5000 1112.0

(meters) NOx Stack Height

Stack Gas Temperature

Stack Gas Velocity

Stack Diameter

Stack Gas Flow Rate

Easting Northing Elevation (g/sec) (meters) (K) (meters/sec) (meters) (cubic meters/min)

OLDST100 Currently Permitted Stack @ 100% Load 278596.5 4901645.3 466.60 6.615 16.76 664.82 21.301631 3.5158 12408.24OLDST090 Currently Permitted Stack @ 90% Load 278596.5 4901645.3 466.60 6.615 16.76 618.16 18.310000 3.5158 10665.61OLDST075 Currently Permitted Stack @ 75% Load 278596.5 4901645.3 466.60 6.030 16.76 618.16 18.310000 3.5158 10665.61OLDST060 Currently Permitted Stack @ 60% Load 278596.5 4901645.3 466.60 5.510 16.76 598.16 15.990000 3.5158 9314.21CS12GENH CS-12 Emergency Generator 8760 Hours 278551.7 4901650.1 467.03 1.779 5.18 699.82 30.480000 0.2032 59.31OREGEMRH OREG2 Emergency Generator 8760 Hours 278658.9 4901694.8 467.21 0.190 4.88 699.82 28.769917 0.1524 31.49


Vertical Stack Source Modeling ParametersUTM Zone 15 (meters

- NAD83)

2/21/2009 Page 1 of 3 CS-12 Model Info V04.xlsx

Capped Stack Parameters

(feet) NOx Stack Height

Stack Gas

Stack Gas Velocity

Stack Diameter

Stack Gas Flow Rate

Easting Northing Elevation (lbs/hr) (feet) (°F) (feet/sec) (feet) (actual cubic feet/min)

WHOHC100 WHOH Capped Stack @ 100% Load 278612.8 4901645.2 1529.8 52.50 60.00 257.0 48.3006 10.7384 262466.1WHOHC090 WHOH Capped Stack @ 90% Load 278612.8 4901645.2 1529.8 52.50 60.00 257.0 44.6498 10.7384 242627.8WHOHC075 WHOH Capped Stack @ 75% Load 278612.8 4901645.2 1529.8 47.86 60.00 257.0 44.6498 10.7384 242627.8WHOHC060 WHOH Capped Stack @ 60% Load 278612.8 4901645.2 1529.8 43.73 60.00 230.0 38.7783 10.7384 210722.0

(meters) NOx Stack Height

Stack Gas

Stack Gas Velocity

Stack Diameter

Stack Gas Flow Rate

Easting Northing Elevation (g/sec) (meters) (K) (meters/sec) (meters) (cubic meters/min)

WHOHC100 WHOH Capped Stack @ 100% Load 278612.8 4901645.2 466.27 6.615 18.29 398.15 14.7220 3.2731 7432.21WHOHC090 WHOH Capped Stack @ 90% Load 278612.8 4901645.2 466.27 6.615 18.29 398.15 13.6093 3.2731 6870.45WHOHC075 WHOH Capped Stack @ 75% Load 278612.8 4901645.2 466.27 6.030 18.29 398.15 13.6093 3.2731 6870.45WHOHC060 WHOH Capped Stack @ 60% Load 278612.8 4901645.2 466.27 5.510 18.29 383.15 11.8196 3.2731 5966.98


Vertical Stack Source Modeling ParametersUTM Zone 15 (meters -

NAD83)


Stack Source Modeling ParametersUTM Zone 15 (meters -

NAD83)


Rectangular Buildings

(meters) (feet) (feet) (feet) (degrees)Easting Northing Elevation Height X-Length Y-Length Angle

AUXBLDG CS-12 Auxiliary Building 278529.4 4901693.4 467.49 20.83 141.50 40.50 90.0COMPBLDG CS-12 Compressor Building 278575.1 4901653.3 466.94 41.00 65.00 60.00 90.0COOLBLDG CS-12 Gas Aftercooler 278593.9 4901603.2 465.74 18.58 40.00 115.00 90.0WHOHBLD OREG 2 WHOH Structure 278610.6 4901650.8 466.37 44.77 37.47 13.45 90.0OILTANK OREG 2 Thermal Oil Surge Tank 278639.8 4901673.5 466.70 14.50 34.00 8.50 0.0OECVAP OREG 2 OEC Unit Vaporizer 278640.7 4901666.7 466.61 12.00 35.00 5.00 0.0OECGEN OREG 2 OEC Generator 278643.8 4901659.9 466.55 8.00 12.00 9.00 0.0OREGELEC OREG 2 Electrical Shelter 278651.8 4901688.5 467.10 14.00 45.00 8.00 0.0OREGPREH OREG 2 Preheater 278640.0 4901669.7 466.64 9.00 45.00 4.00 0.0OECTURB OREG 2 OEC Turbine 278647.5 4901660.4 466.62 8.00 21.00 6.50 0.0

Model ID DescriptionRectangular Building Modeling Parameters

UTM (meters - NAD83)


Documents

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