Draft Air Emission Permit No. 08900012- 101 1. 1 · Draft Air Emission Permit No. 08900012- 101. This technical support document (TSD) is intended for all parties interested in the

Technical Support Document, Permit Number: 08900012-101 Page 1 of 8

. Technical Support Document

For Draft Air Emission Permit No. 08900012-101

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)

Great Lakes Gas Transmission Limited Partnership (owner) Great Lakes Gas Transmission Company (operator) 5250 Corporate Drive 717 Texas Avenue, Suite 2400 Houston, Texas 77002

Great Lakes Gas Transmission - Station 2 10950 260th St NE Newfolden MN 56738

Contact: Melinda Holdsworth Phone: 832-320-5665

1.2 Facility description

Great Lakes Gas Transmission Company, as operator and agent for Great Lakes Gas Transmission Limited Partnership (Great Lakes), operates nearly 2,000 miles of large-diameter underground pipeline, which transports natural gas for delivery to customers in the Midwestern and northeastern United States and eastern Canada. The Great Lakes pipeline system starts at an interconnection with TransCanada Pipelines Limited (TransCanada) near the Manitoba- Minnesota border and traverses northern Minnesota, northern Wisconsin, and the upper and lower peninsulas of Michigan. The pipeline's 14 compressor stations, placed approximately 75 miles apart, operate to keep natural gas moving through the system. The Permittee operates a natural gas pipeline compressor station (Standard Industrial Classification code 4922) located approximately 6 miles southeast of the city of Newfolden, Marshall County, Minnesota. The primary function of the facility, Thief River Falls Compressor Station No. 2, is to provide motive force for natural gas flowing through the pipeline. Great Lakes operates two natural gas-fired turbines, one natural gas-fired standby electrical generator, and one 3.5 mmBtu boiler. EQUI 1 is a Rolls Royce Avon 101G natural gas-fired turbine installed in 1971 with a maximum ambient rating of 18,000 HP. EQUI 3 is a Rolls Royce Avon 76G natural gas-fired turbine installed in 1972 with a maximum ambient rating of 16,000 HP. EQUI 2 is a natural gas-fired standby electrical generator installed in 1971 and rated at 250 HP (4-stroke rich burn). The main pollutants of concern are products of combustion such as carbon monoxide and nitrogen oxides.

1.3 Description of the activities allowed by this permit action

This permit action is Part 70 Reissuance. No changes are authorized by this permit.

1.4 Description of notifications and applications included in this action Table 2. Notifications and applications included in this action

Date received Application/Notification type and description 12/05/2013 Part 70 Reissuance (IND20130001)


1.5 Facility emissions

Table 3. 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 11.6 11.6 11.6 0.018 443 987 184100 3.95 1.40 2.08 Total facility actual emissions (2015) 0 0 0 0.001 0.146 0.124 * 0.002 *

*Not reported in Minnesota emission inventory. Table 4. Facility classification

Classification Major Synthetic minor/area Minor/Area

New Source Review X Part 70 X Part 63 X

1.6 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 was updated to reflect current MPCA templates and standard citation formatting. · Due to the MPCA’s recent database change, the permit has a new format. Emissions units (EU) now have

identifiers that begin with EQUI. Buildings (BG) and stack/vents (SVs) are structures, with identifiers that begin with STRU.

· GP 001 for the turbines was removed from the permit. Requirements have been moved to the individual units (EQUI 1 and 3) in the permit.

· Boiler EQUI 4 was added to the permit. This emission unit was added to the facility in 2008 and qualified as an insignificant activity in previous permit actions. Due to changes in Minn. R. 7007.1300, subp. 3(I) since the last permit action, this unit no longer qualifies as an insignificant activity.

· 40 CFR pt. 63, subp. ZZZZ requirements were added for EQUI 2 (formerly EU 003) the Standby Electrical Generator.

2. Regulatory and/or statutory basis

2.1 New source review (NSR)

The facility is an existing major source under New Source Review regulations. No changes are authorized by this permit.

2.2 Part 70 permit program


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

2.3 New source performance standards (NSPS) The Permittee has stated that no New Source Performance Standards apply to the operations at this facility. Neither of the existing turbines (EQUI 1 and 3) is subject to an NSPS. The turbines were constructed in 1971 and are therefore not subject to 40 CFR pt. 60, subp. GG. If either turbine is changed such that it is modified or reconstructed, 40 CFR pt. 60, subp. KKKK would apply. The reciprocating engine (EQUI 2) at the facility, constructed in 1972, is an existing facility under 40 CFR pt. 60, subp. JJJJ; therefore, it is not subject to this standard.

2.4 National emission standards for hazardous air pollutants (NESHAP) The facility is an area source for hazardous air pollutants. 40 CFR pt. 63, Subp. ZZZZ—National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines The 250 hp reciprocating engine (EQUI 2), constructed in 1972, is an existing affected source under 40 CFR pt. 63, subp. ZZZZ. Under this standard, an existing unit commenced construction prior to June 12, 2006. The compliance date for this emission unit was October 19, 2013.

40 CFR pt. 63, Subp. JJJJJJ—National Emission Standards for Hazardous Air Pollutants for Industrial, Commercial, and institutional Boilers Area Sources The boiler (EQUI 4) is a gas-fired boiler as defined in 40 CFR §63.11237; therefore, this boiler is not subject to 40 CFR pt. 63, subpart JJJJJJ and to any requirements of this subpart as indicated under 40 CFR § 63.11195. 40 CFR pt. 63, subp. YYYY – National Emission Standards for Hazardous Air Pollutants for Stationary Combustion Turbines This standard applies at major sources. Since this facility is an area source of HAPs, 40 CFR pt. 63, subp. YYYY does not apply.

2.5 Acid rain program The facility is not subject to Acid Rain regulations.

2.6 Compliance assurance monitoring (CAM) The facility does not use control to meet emission limits; therefore, CAM does not apply.

2.7 Minnesota State Rules Portions of the facility are subject to the following Minnesota Standards of Performance:

· Minn. R. 7011.0515 Standards of Performance for New Indirect Heating Equipment · Minn. R. 7011.2300 Standards of Performance for Stationary Internal Combustion Engines


Table 5. Regulatory overview of facility

Subject item* Applicable regulations Rationale EQUI 1 - Turbine EQUI 3 - Turbine

Minn. R. 7011.2300 Minn. R. 7005.0100, subp. 35a Title I Condition: Avoid major modification under 40 CFR 52.21

Standards of Performance for Stationary Internal Combustion Engines Potential to Emit. Fuels limited to Natural Gas. Prevention of Significant Deterioration. The Permit contains provisions for gas turbine replacement activities. The restrictions of the authorization allow the change to avoid being a major modification under NSR and prohibits any change that would trigger an NSPS.

EQUI 2 - Reciprocating IC Engine

Minn. R. 7011.2300 Minn. R. 7005.0100, subp. 35a 40 CFR pt. 63, subp. ZZZZ

Standards of Performance for Stationary Internal Combustion Engines Potential to Emit. Fuels limited to Natural Gas. National Emission standards for Stationary Internal Combustion Engines. This unit is an existing emergency engine at an area source of HAPs. Work practice standards apply.

EQUI 4 - Boiler Minn. R. 7011.0515 Standards of Performance for Indirect Heating Equipment. Determination of applicable limit from rule: · the unit was constructed in 2008; · the facility is located outside the cities in Table I; · the unit capacity is less than 250 MMBtu/hr; and · the facility has greater than 250 MMBtu/hr of indirect

heating equipment. *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 a summary of the PTE of the facility and detailed spreadsheets and supporting information prepared by the MPCA and the Permittee. The Permittee has elected to update some of the assumptions underlying the emissions calculations, such as the heating value of natural gas and updated emission factors for sulfur dioxide. This has resulted in changes in emissions for some pollutants, but does not result in any changes in applicability of any rules. There are no changes to capacities, operations, or fuels used described by these updated calculations. Generally, emission calculations rely on AP-42 emission factors, except for NOx, CO and SO2 for the combustion turbines and greenhouse gas (GHG) emissions, as follows: · NOx and CO emissions factors for the combustion turbines, EQUI 1 and 3, are based on stack test data, as

discussed in the TSD for permit number 08900012-003. Because the most recent stack testing for these units was conducted in 2005, the permit includes requirements to conduct CO and NOx performance tests to verify the emission factors. Additionally, stack test verification of the emission factor is only needed on a 10 year schedule for the purposes of emissions inventory under Minn. R. ch. 7019, therefore, no test frequency plan requirements are included in this permit action, and these are not recurring test requirements. The need for further testing can be evaluated at the next reissuance.

· SO2 emission factors for the turbines have been refined. AP-42 uses the sulfur content of the fuel as part of determining the emission factor. This refinement was triggered by the revisions to Minn. R. 7011.2300, which limits SO2 to less than or equal to 0.0015 lb/mmBtu. AP-42, Table 3.1.2a uses a formula for natural gas turbines SO2 emission factor, which assumes all sulfur is converted to SO2. SO2

= 0.94S, where S is the


percent sulfur in fuel. The Permittee conducted testing to determine the sulfur content of the fuel. Based on the tests, the Permittee has elected to use a sulfur content of 0.025 ppm. Additionally, a review of online sources suggests that this sulfur content is in the range typically expected for pipeline natural gas.

· For all combustion equipment, greenhouse gas (GHG) emissions are based on 40 CFR pt. 98 emission factors and global warming potentials.

3.2 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 following table summarizes the monitoring requirements. Table 6. Monitoring

Subject Item* Requirement (basis)

What is the monitoring? Why is this monitoring adequate?

EQUI 1 (Turbine Unit 201) EQUI 2 (Standby Electrical Generator) EQUI 3 (Turbine Unit 202)

Opacity <= 20 percent opacity Sulfur Dioxide <= 0.50 pounds per million Btu heat input Sulfur Dioxide <= 0.0015 pounds per million Btu heat input This limit is effective on January 31, 2018. [Minn. R. 7011.2300]

Fuel records. The Permittee meets the requirement by using only natural gas in these units. Therefore, recordkeeping of fuel use is adequate to demonstrate continuous compliance.


Subject Item* Requirement (basis)

What is the monitoring? Why is this monitoring adequate?

EQUI 2 (Standby Electrical Generator)

Inspect spark plugs, hoses, and belts; Change oil and filter; non-resettable hour meter (40 CFR pt. 63, subp. ZZZZ)

Recordkeeping. Monitoring required by the NESHAP is adequate to demonstrate compliance.

EQUI 4 (3.5 mmBtu/hr Natural Gas Boiler)

Particulate Matter <= 0.40 pounds per million Btu heat input Opacity <= 20 percent opacity [Minn. R. 7011.0515]

None This unit uses natural gas; 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. Since this is a permit condition, the semi-annual deviations report will document any deviations from this condition. Design based PTE for each unit, using AP-42, is 0.0075 compared to the rule limit of 0.40 lb/MMBtu.

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

3.3 Insignificant activities Great Lakes Gas Transmission - Station 2 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

Brazing, soldering or welding equipment

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

The Permittee uses an arc welder to repair equipment or fabricate parts. For this unit, based on EPA published emissions factors, it is highly unlikely that they could violate the applicable requirement. In addition, these units are typically operated and vented inside a building, so testing for PM or opacity is not feasible.

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

PM ≤ 0.6, depending on year constructed Opacity ≤ 20% with exceptions (Minn. R. 7011.0510)

The Permittee operates space heaters with a total capacity of 0.6 mmBtu/hr. For these units, based on the fuels used and EPA published emissions factors, it is highly unlikely that they could violate the applicable requirements.


Insignificant activity General applicable emission limit Discussion

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)

The Permit contains a general requirement that this standard be met. Vehicle traffic is limited to employee traffic and maintenance vehicles.

Total facility coating and cleaning usage at the stationary source that meets the requirements of Minn. R. 7008.4100 (200 gallons or 2000 lb VOC and 8000 lb of particulates)

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

The Permittee uses approximately five gallons per year of VOC containing parts cleaning fluid in its parts cleaning bin. These activities are not expected to generate particulate matter emissions. The Permittee needs to maintain the records specified in 7008.4100 to demonstrate the activity qualifies as a conditionally insignificant activity.

3.4 Permit organization

In general, the permit meets the MPCA Tempo Guidance for ordering and grouping of requirements. One area where this permit deviates slightly from Tempo guidance is in the use of appendices. While appendices are fully enforceable parts of the permit, in general, any requirement that the MPCA thinks should be electronically tracked (e.g., limits, submittals, etc.), should be in the Requirements table in Tempo. The main reason is that the appendices are word processing sections and are not part of the electronic tracking system. Violation of the appendices can be enforced, but the computer system will not automatically generate the necessary enforcement notices or documents. Staff must generate these. Appendix A identifies the facility’s insignificant activities with their general applicable requirements. It is reasonable to list these activities in an appendix because there are no requirements that need to be tracked by the MPCA.

3.5 Comments received This section will be completed after the Public Comment and EPA Review periods.

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 Great Lakes Gas Transmission - Station 2 the MPCA has reasonable assurance that the proposed operation of the emission facility, as described in the Air Emission Permit No. 08900012-101 and this TSD, will not cause or contribute to a violation of applicable federal regulations and Minnesota Rules. Staff members on permit team: Sarah Sevcik (permit engineer)

Peggy Bartz (peer reviewer) Beckie Olson (permit writing assistant and data coordinator) Laurie O’Brien (administrative support) Marc Severin (Compliance) Matt Snorek (Enforcement)

TEMPO360 Activities: Part 70 Reissuance (IND20130001)


Attachments: 1. PTE summary and detailed calculation spreadsheets 2. Subject item inventory and facility requirements

Attachment 1: PTE Summary and detailed calculation spreadsheets

Great Lakes Gas TransmissionThief River Falls Compressor Station No. 2

08900012‐101

Previous

unit IDSource Manufacturer Model/Type

Rated

Horsepower

Heat Input

(MMBTU/hr)

EU 001Rolls Royce Avon 1016G Natural Gas‐Fired Gas Turbine

Rolls Royce Avon 101G 18,000 187.20

EU 002Rolls Royce Avon 76G Natural Gas‐Fired Gas Turbine

Rolls Royce Avon 76G 16,000 166.40

EU 003Waukesha Model F1197G, natural gas‐fired generator engine

Waukesha F1197G 201 2.00

NAYork‐Shipley Model SPWFV‐80‐N 93273 natural gas‐fired boiler

York‐Shipley SPWFV‐80‐N 93273 N/A 3.35

Source List Great Lakes Gas TransmissionThief River Falls Compressor Station No. 2

Regulated Pollutants, Potential to Emit Summary

Great Lakes Gas Transmission

Thief River Falls Compressor Station No. 2

Permit # 08900012‐101

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

EQUI 1Rolls Royce Avon 1016G Natural Gas‐Fired Gas Turbine 18,000 ‐‐ 187.20 47.2 206.8 116.7 511.3 0.4 1.9 1.4 6.0 0.000 0.002

EQUI 3Rolls Royce Avon 76G Natural Gas‐Fired Gas Turbine 16,000 ‐‐ 166.40 49.1 215.2 100.9 442.2 0.4 1.7 1.2 5.3 0.000 0.002

EQUI 2Waukesha Model F1197G, natural gas‐fired generator engine 250 4SRB 2.00 4.5 19.9 7.4 32.6 0.1 0.3 0.0 0.2 0.001 0.005

EQUI 4York‐Shipley Model SPWFV‐80‐N 93273 natural gas‐fired boiler N/A ‐‐ 3.35 0.3 1.4 0.3 1.2 0.0 0.1 0.0 0.1 0.002 0.009

Total Emissions 101.2 443.3 225.4 987.2 0.9 4.0 2.7 11.6 0.004 0.018

Unit DescriptionUnit HP Type SO2Heat Input

Emission Rates

NOx CO VOC PM

Regulated Pollutants, PTE Great Lakes Gas Transmission Thief River Falls Compressor Station No. 2

Permit # 08900012‐101Single HAP Total HAP

Emission

Factor

Emission

Factor

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

EQUI 1Rolls Royce Avon 1016G Natural Gas‐Fired Gas Turbine (Formerly EU001) 18,000 ‐‐ 7.1E‐04 0.15 0.65 1.0E‐03 0.21 0.94

EQUI 3Rolls Royce Avon 76G Natural Gas‐Fired Gas Turbine(Formerly EU002) 16,000 ‐‐ 7.1E‐04 0.13 0.57 1.0E‐03 0.19 0.83

EQUI 2Waukesha Model F1197G, natural gas‐fired generator engine (Formerly EU003) 250 4SRB 2.1E‐02 0.04 0.18 3.2E‐02 0.06 0.28

EQUI 4York‐Shipley Model SPWFV‐80‐N 93273 natural gas‐fired boiler N/A ‐‐ 7.4E‐05 0.0002 0.001 1.9E‐03 0.01 0.03

Total Emissions 0.32 1.40 0.47 2.08

2) Emissions provided are for representation purposes only; emission and operational rates are not intended to convey any limitations or restriction

Hazardous Air Pollutants, Emissions Summary



Notes on Emission Estimation Methods:

1) Formaldehyde (HCHO) and Total HAP emission factors for turbines are from AP‐42 Table 3.1‐3 "Emission Factors for Hazardous Air Pollutants fromNatural Gas‐Fired Stationary Gas Turbines" (4/00).

Potential Emissions Potential EmissionsTitle V

Unit IDUnit Description HP Type

Formaldehyde (HCHO) Emissions Total HAP Emissions

Hazardous Air Pollutants, PTE Great Lakes Gas Transmission Thief River Falls Compressor Station No. 2

TITLE V RENEWALGreat Lakes Gas Transmission

Thief River Falls Compressor Station No. 2Permit # 08900012‐101

Emission Unit ID EQUI 1 (Formerly EU 001)Unit ID No. Unit 201

Description of Unit Rolls Royce Avon 101G Natural Gas‐Fired TurbineManufacturer Rolls RoyceDate of Construction/Modification 1971Fuel Used Natural GasMinimum Higher Heating Value (HHV) 918 Btu/scfMaximum Higher Heating Value (HHV) 1,020 Btu/scfRated Horsepower (hp) 18,000 hpHeat Rate (Btu/bhp‐hr) 10,400 Btu/bhp‐hrHeat Input (MMBtu/hr) 187.20 MMBtu/hrMaximum Hourly Fuel Consumption 203,922 scf/hrControl Device N/AStack Designation STRU 5

Annual Hours of Operation 8,760 hr/yrAnnual Fuel Consumption 1,786.35 MMscf/yr

Emission Factors:

Pollutant Emission Factor Emission Factor

Units

Emission

Factor Source

NOx 0.227 lb/MMBtu aCO 0.5612 lb/MMBtu aVOC 2.1E‐03 lb/MMBtu bPM10 6.6E‐03 lb/MMBtu bPM2.5 6.6E‐03 lb/MMBtu bSO2 2.4E‐06 lb/MMBtu b,c

c. Permittee sampled gas and measured 0.025ppm sulfur, resulting in fuel sulfur content of 0.00000POTENTIAL EMISSIONS:

PollutantEmission Rate

(lb/hr)

Calculation

Methodology

Potential

Emissions d

(ton/yr)NOx 47.22 c 206.81CO 116.73 c 511.28 VOC 0.44 c 1.91PM/PM10 1.37 c 6.01PM2.5 1.37 c 6.01SO2 0.0005 c 0.0021

b AP‐42 Table 3.1‐2a "Emission Factors for Criteria Pollutants and Greenhouse Gases from Stationary Gas Turbines" (4/00). The SO2 Emission Factor is 0.94S with the footnote: All sulfur in the fuel is assumed to be converted to SO2. S = percent sulfur in fuel. Example, if sulfur content in the fuel is 3.4 percent, then S = 3.4. If S is not available, use 3.4 E‐03 lb/MMBtu for natural gas turbines, and 3.3 E‐02 lb/MMBtu for distillate oil turbines (the equations are more accurate)."

a Calculated from May 9‐10, 1995 Emission Testing results. Verified by March 31‐April 1, 2005, Emissions Testing Results.

Unit 201 TurbineGreat Lakes

Gas Transmission Thief River Falls Compressor Station No. 2



Emission Unit ID EQUI 1 (Formerly EU 001)Unit ID No. Unit 201

Description of Unit Rolls Royce Avon 101G Natural Gas‐Fired Turbine

HAP Calculated Emissions:

Emission Factor

Pollutant (lb/MMBtu)e (lb/hr)f (tons/yr)g

HAPs:1,3‐Butadiene 4.3E‐07 8.94E‐05 0.0004

Acetaldehyde 4.0E‐05 8.32E‐03 0.0364

Acrolein 6.4E‐06 1.33E‐03 0.0058

Benzene 1.2E‐05 2.50E‐03 0.0109

Ethylbenzene 3.2E‐05 6.66E‐03 0.0292

Formaldehyde 7.1E‐04 1.48E‐01 0.6468

Naphthalene 1.3E‐06 2.70E‐04 0.0012

PAH 2.2E‐06 4.58E‐04 0.0020

Propylene Oxide 2.9E‐05 6.03E‐03 0.0264

Toluene 1.3E‐04 2.70E‐02 0.1184

Xylene 6.4E‐05 1.33E‐02 0.0583

Total HAP 1.03E‐03 0.21 0.94

g Emission Rate (ton/yr) = (Emission Rate, lb/hr) * (Annual Hours of Operation, hrs/yr) * (1

f Emission Rate (lb/hr) = (Emission Factor, lb/MMBtu) * (Max Fuel Consumption, scf/hr) * (Maximum HHV, Btu/scf) * (MM/1,000,000)

e AP‐42 Table 3.1‐3 "Emission Factors for Hazardous Air Pollutants from Natural Gas‐Fired Stationary Gas Turbines" (4/00).

d Emission Rate (ton/yr) = (Emission Rate, lb/hr) * (Annual Operation, hrs/yr) * (1 ton/2000 lb)

Potential Emissions

c Emission Rate (lb/hr) = (Emission Factor, lb/MMBtu) * (Max Fuel Consumption, scf/hr) * (Maximum HHV, Btu/scf) * (MM/1,000,000)



TITLE V RENEWAL



Permit # 08900012‐101

Emission Unit ID EQUI 1 (Formerly EU 001)Unit ID No.: Unit 201

Description of Unit: Rolls Royce Avon 101G Natural Gas‐Fired Turbine

Potential Greenhouse Gas (GHG) Emission Calculations[2]

Pollutant

Uncontrolled

Emission

Factor[2]Factor Units[2] Emissions (lb/hr) Emissions (TPY)

Global Warming

Potential

(GWP)[2]

CO2e

Emissions

(lb/hr)

CO2e Emissions

(TPY)

CO2 53.06 kg CO2/MMBtu 21898.15 95913.90 1 21898.15 95913.90

CH4 0.001 kg CH4/MMBtu 0.41 1.81 25 10.3176 45.19

N2O 0.0001 kg N2O/MMBtu 0.04 0.18 298 12.2986 53.87

TOTAL GHGs ‐‐ ‐‐ 21898.60 95915.88 ‐‐ ‐‐ ‐‐TOTAL GHGs (CO2e) ‐‐ ‐‐ ‐‐ ‐‐ ‐‐ 21920.77 96012.96

[2] Based on 40 CFR 98 Subpart C, 98.33(a)(1)(i), Tier 1 Methodology, Equation C‐1 and using source specific heat input.GHG Emissions (lb/hr) = EFGHG (kg/MMBtu) * 2.204623 lb/kg * Source Specific Heat Input (MMbtu/hr)

GHG Emissions (TPY) = GHG Emissions (lb/hr) * Annual Hoperating Hours (hr/yr) * 1 Ton/2000 lbCO2e Emissions (TPY) = Σ (GHG Emissions (tpy) * GWP)

Where: EFGHG =

Heat Input = Btu/hp‐hr x Site‐rated hp x (1 MMBtu/1,000,000 Btu) = MMBtu/hr

GWP = Global Warming Potentials, 40 CFR 98, Subpart A, Table A‐1

[1] Heat input based on fuel consumption and permitted HP.

Fuel‐specific default CO2, CH4, or N2O emission factors from Table C‐1 for CO2 (Natural gas ‐ Weighted



Emission Unit ID EQUI 3 Formerly EU 002Unit ID No. Unit 202

Description of Unit Rolls Royce Avon 76G Natural Gas‐Fired TurbineManufacturer Rolls RoyceDate of Construction/Modification 1971Fuel Used Natural GasMinimum Higher Heating Value (HHV) 918 Btu/scfMaximum Higher Heating Value (HHV) 1,020 Btu/scfRated Horsepower (hp) 16,000 hpHeat Rate (Btu/bhp‐hr) 10,400 Btu/bhp‐hrHeat Input (MMBtu/hr) 166.40 MMBtu/hrMaximum Hourly Fuel Consumption 181,264 scf/hrControl Device N/AStack Designation STRU 4

Annual Hours of Operation 8,760 hr/yrAnnual Fuel Consumption 1,587.87 MMscf/yr

Emission Factors:

Pollutant Emission Factor Emission Factor

Units

Emission Factor

Source

NOx 0.2657 lb/MMBtu aCO 0.5460 lb/MMBtu aNM/NE VOC 2.1E‐03 lb/MMBtu bPM10 6.6E‐03 lb/MMBtu bPM2.5 6.6E‐03 lb/MMBtu bSO2 2.4E‐06 lb/MMBtu b,c

c. Permittee sampled gas and measured 0.025ppm sulfur, resulting in fuel sulfur content of 0.000002POTENTIAL EMISSIONS:


(lb/hr)

Calculation

Methodology

Potential

Emissions d

(ton/yr)NOx 49.12 c 215.17CO 100.95 c 442.16 VOC 0.39 c 1.70PM/PM10 1.22 c 5.34PM2.5 1.22 c 5.34

a Calculated from May 9‐10, 1995 Emission Testing results. Verified in March 31‐April 1, 2005, Emissions Testing Results.

b AP‐42 Table 3.1‐2a "Emission Factors for Criteria Pollutants and Greenhouse Gases from Stationary Gas Turbines" (4/00). The SO2 Emission Factor is 0.94S with the footnote: All sulfur in the fuel is assumed to be converted to SO2. S = percent sulfur in fuel. Example, if sulfur content in the fuel is 3.4 percent, then S = 3.4. If S is not available, use 3.4 E‐03 lb/MMBtu for natural gas turbines, and 3.3 E‐02 lb/MMBtu for distillate oil turbines (the equations are more accurate)."





Emission Unit ID EQUI 3 Formerly EU 002Unit ID No. Unit 202

Description of Unit Rolls Royce Avon 76G Natural Gas‐Fired TurbineSO2 0.0004 c 0.0019


Emission Factor


HAPs:1,3‐Butadiene 4.3E‐07 7.95E‐05 0.0003

Acetaldehyde 4.0E‐05 7.40E‐03 0.0324

Acrolein 6.4E‐06 1.18E‐03 0.0052

Benzene 1.2E‐05 2.22E‐03 0.0097

Ethylbenzene 3.2E‐05 5.92E‐03 0.0259

Formaldehyde 7.1E‐04 1.31E‐01 0.5750

Naphthalene 1.3E‐06 2.40E‐04 0.0011

PAH 2.2E‐06 4.07E‐04 0.0018

Propylene Oxide 2.9E‐05 5.36E‐03 0.0235

Toluene 1.3E‐04 2.40E‐02 0.1053

Xylene 6.4E‐05 1.18E‐02 0.0518

Total HAP 1.03E‐03 0.19 0.83

g Emission Rate (ton/yr) = (Emission Rate, lb/hr) * (Annual Hours of Operation, hrs/yr) * (1

Potential Emissions

c Emission Rate (lb/hr) = (Emission Factor, lb/MMBtu) * (Max Fuel Consumption, scf/hr) * (Maximum HHV, Btu/scf) * (MM/1,000,000)d Emission Rate (ton/yr) = (Emission Rate, lb/hr) * (Annual Operation, hrs/yr) * (1 ton/2000 lb)

e AP‐42 Table 3.1‐3 "Emission Factors for Hazardous Air Pollutants from Natural Gas‐Fired Stationary Gas Turbines" (4/00). f Emission Rate (lb/hr) = (Emission Factor, lb/MMBtu) * (Max Fuel Consumption, scf/hr) * (Maximum HHV, Btu/scf) * (MM/1,000,000)





Emission Unit ID EQUI 3Unit ID No.: Unit 202Description of Unit: Rolls Royce Avon 76G Natural Gas‐Fired Turbine


Pollutant

Uncontrolled

Emission

Factor[2]Factor Units[2]

Emissions

(lb/hr)

Emissions

(TPY)

Global

Warming

Potential

(GWP)[2]

CO2e

Emissions

(lb/hr)

CO2e

Emissions

(TPY)

CO2 53.06 kg CO2/MMBtu 19465.02 85256.80 1 19465.02 85257

CH4 0.001 kg CH4/MMBtu 0.37 1.61 25 9.1712 40

N2O 0.0001 kg N2O/MMBtu 0.04 0.16 298 10.9321 48

TOTAL GHGs ‐‐ ‐‐ 19465.43 85258.56 ‐‐ ‐‐ ‐‐TOTAL GHGs (CO2e) ‐‐ ‐‐ ‐‐ ‐‐ ‐‐ 19485.13 85345



Where: EFGHG =

Heat Input = Btu/hp‐hr x Site‐rated hp x (1 MMBtu/1,000,000 Btu) = MMBtu/hrGWP = Global Warming Potentials, 40 CFR 98, Subpart A, Table A‐1


Fuel‐specific default CO2, CH4, or N2O emission factors from Table C‐1 for CO2 (Natural gas

TITLE V RENEWAL



Emission Unit ID EQUI 2 Formerly EU 003Unit ID No.

Description of Unit

Manufacturer Waukesha

Date of Construction/Modification 1971

Stroke Cycle 4‐StrokeType of Burn Rich‐BurnFuel Used Natural GasMinimum Higher Heating Value (HHV) 918 Btu/scf

Maximum Higher Heating Value (HHV) 1,020 Btu/scf

Rated Horsepower (hp) 250 hp

Heat Rate (Btu/bhp‐hr) 8,000 Btu/bhp‐hrHeat Input (MMBtu/hr) 2.00 MMBtu/hr

Maximum Hourly Fuel Consumption 2,179 scf/hr

Control Device N/A

Stack Designation STRU 4Annual Hours of Operation 8,760 hr/yr

Annual Fuel Consumption 19.08 MMscf/yr

Emission Factors:

Pollutant Emission

Factor Emission Factor

Units

Emission

Factor Source

NOx 2.27 lb/MMBtu a

CO 3.72 lb/MMBtu a

VOC 0.0296 lb/MMBtu a

PM/PM10 0.019 lb/MMBtu a

PM2.5 0.019 lb/MMBtu aSO2 5.88E‐04 lb/MMBtu a

POTENTIAL EMISSIONS:


(lb/hr)

Calculation

Methodology

Potential

Emissions d

(ton/yr)

NOx 4.54 b 19.89

CO 7.44 b 32.59

VOC 0.06 b 0.26

PM/PM10 0.04 c 0.17

PM2.5 0.04 c 0.17SO2 0.001 c 0.005

Sample Calculation:b Emission Rate (lb/hr) = (Emission Factor, gm/hp‐hr) / (1 lb/453.6 gm) * (Rated Horsepower, hp)



Emission Factor


HAPs:

1,1,2,2‐Tetrachloroethane 2.53E‐05 5.06E‐05 0.0002

1,1,2‐Trichloroethane 1.53E‐05 3.06E‐05 0.0001

1,3‐Butadiene 6.63E‐04 1.33E‐03 0.0058

1,3‐Dichloropropene 1.27E‐05 2.54E‐05 0.0001

Acetaldehyde 2.79E‐03 5.58E‐03 0.0244

Acrolein 2.63E‐03 5.26E‐03 0.0230

Benzene 1.58E‐03 3.16E‐03 0.0138

Carbon Tetrachloride 1.77E‐05 3.54E‐05 0.0002

Chlorobenzene 1.29E‐05 2.58E‐05 0.0001

Chloroform 1.37E‐05 2.74E‐05 0.0001

Ethylbenzene 2.48E‐05 4.96E‐05 0.0002

Ethylene Dibromide 2.13E‐05 4.26E‐05 0.0002

Formaldehyde 2.05E‐02 4.10E‐02 0.1796

Methanol 3.06E‐03 6.12E‐03 0.0268

Methylene Chloride 4.12E‐05 8.24E‐05 0.0004

Naphthalene 9.71E‐05 1.94E‐04 0.0009

PAH 1.41E‐04 2.82E‐04 0.0012

Styrene 1.19E‐05 2.38E‐05 0.0001

Toluene 5.58E‐04 1.12E‐03 0.0049

Vinyl Chloride 7.18E‐06 1.44E‐05 0.0001Xylene 1.94E‐04 3.88E‐04 0.0017

Total HAP 3.24E‐02 0.06 0.28

g Emission Rate (ton/yr) = (Emission Rate, lb/hr) * (Annual Hours of Operation, hrs/yr) * (1 ton/2000 lb)

Potential Emissions

e AP‐42 Table 3.2‐3 "Uncontrolled Emission Factors for 4‐Stroke Rich Burn Engines" (7/00).

Waukesha Model F1197G, natural gas‐fired

c Emission Rate (lb/hr) = (Emission Factor, lb/MMBtu) * (Rated Horsepower, hp) * (Heat Rate, Btu/bhp‐hr) * (MM/1,000,000)

a AP‐42 Table 3.2‐3 "Uncontrolled Emission Factors for 4‐Stroke Rich Burn Engines" (7/00).

f Emission Rate (lb/hr) = (Emission Factor, lb/MMBtu) * (Rated Horsepower, hp) * (Heat Rate, Btu/bhp‐hr) * (MM/1,000,000)

Waukesha GeneratorGreat Lakes




EQUI 2Emission Unit ID (Formerly EU 3)Unit ID No.: 0Description of Unit: Waukesha Model F1197G, natural gas‐fired generator engine, 201 hp


Pollutant

Uncontrolled

Emission


Emissions

(lb/hr)Emissions (TPY)

Global

Warming

Potential

(GWP)[2]

CO2e

Emissions

(lb/hr)

CO2e

Emissions

(TPY)

CO2 53.06 kg CO2/MMBtu 233.95 1024.72 1 233.95 1024.72

CH4 0.001 kg CH4/MMBtu 0.0044 0.0193 25 0.11 0.48

N2O 0.0001 kg N2O/MMBtu 0.0004 0.0019 298 0.13 0.58

TOTAL GHGs ‐‐ ‐‐ ‐‐ ‐‐ ‐‐TOTAL GHGs (CO2e) ‐‐ ‐‐ ‐‐ ‐‐ ‐‐ 234.20 1025.78



Where: EFGHG =

Heat Input = Btu/hp‐hr x Site‐rated hp x (1 MMBtu/1,000,000 Btu) = MMBtu/hrGWP = Global Warming Potentials, 40 CFR 98, Subpart A, Table A‐1


Fuel‐specific default CO2, CH4, or N2O emission factors from Table C‐1 for CO2 (Natural gas ‐



Emission Unit No. EQUI 4Unit ID No.Description of Unit Natural gas‐fired boilerManufacturer York Shipley SPWFV‐80‐N 93273Date of Construction/Modification 10/2008Fuel Used Natural GasMaximum Higher Heating Value (HHV) 1,020 Btu/scfHeat Input (MMBtu/hr) 3.35 MMBtu/hrMaximum Hourly Fuel Consumption 3,284 scf/hr

Annual Hours of Operation 8,760 hr/yrAnnual Fuel Consumption 28.77 MMscf/yr

Emission Factors:

Pollutant Emission Factor

(lb/MMscf)

Emission Factor

Source

NOx 100 aCO 84 a VOC 5.5 b

PM/PM10 7.6 b

PM2.5 7.6 bSO2 0.6 bLead 0.0005 b



(lb/hr)

Calculation

Methodology

Potential

Emissions d

(ton/yr)NOx 0.33 c 1.44CO 0.28 c 1.21VOC 0.02 c 0.08PM/PM10 0.02 c 0.11PM2.5 0.02 c 0.11SO2 0.002 c 0.01Lead 0.000002 c 7.19E‐06Sample Calculation:


Emission Factor

Pollutant (lb/MMscf)e (lb/hr)f (tons/yr)g

HAPs:

2‐Methylnaphthalene 2.40E‐05 7.88E‐08 3.45E‐073‐Methylchloranthrene 1.80E‐06 5.91E‐09 2.59E‐087,12‐Dimethylbenz(a)anthracene 1.60E‐05 5.25E‐08 2.30E‐07Acenaphthene 1.80E‐06 5.91E‐09 2.59E‐08Acenaphthylene 1.80E‐06 5.91E‐09 2.59E‐08Anthracene 2.40E‐06 7.88E‐09 3.45E‐08Benz(a)anthracene 1.80E‐06 5.91E‐09 2.59E‐08Benzene 2.10E‐03 6.90E‐06 3.02E‐05Benzo(a)pyrene 1.20E‐06 3.94E‐09 1.73E‐08Benzo(b)fluoranthene 1.80E‐06 5.91E‐09 2.59E‐08Benzo(g,h,i)perylene 1.20E‐06 3.94E‐09 1.73E‐08Benzo(k)fluoranthene 1.80E‐06 5.91E‐09 2.59E‐08Chrysene 1.80E‐06 5.91E‐09 2.59E‐08Dibenzo(a,h)anthracene 1.20E‐06 3.94E‐09 1.73E‐08Dichlorobenzene 1.20E‐03 3.94E‐06 1.73E‐05Fluoranthene 3.00E‐06 9.85E‐09 4.32E‐08Fluorene 2.80E‐06 9.20E‐09 4.03E‐08Formaldehyde 7.50E‐02 2.46E‐04 1.08E‐03Indeno(1,2,3‐c,d)pyrene 1.80E‐06 5.91E‐09 2.59E‐08n‐Hexane 1.80E+00 5.91E‐03 2.59E‐02Naphthalene 6.10E‐04 2.00E‐06 8.78E‐06PAH 2.14E‐05 7.03E‐08 3.08E‐07Phenanthrene 1.70E‐05 5.58E‐08 2.45E‐07Pyrene 5.00E‐06 1.64E‐08 7.19E‐08Toluene 3.40E‐03 1.12E‐05 4.89E‐05Arsenic 2.00E‐04 6.57E‐07 2.88E‐06Beryllium 1.20E‐05 3.94E‐08 1.73E‐07Cadmium 1.10E‐03 3.61E‐06 1.58E‐05Chromium 1.40E‐03 4.60E‐06 2.01E‐05Cobalt 8.40E‐05 2.76E‐07 1.21E‐06Manganese 3.80E‐04 1.25E‐06 5.47E‐06Mercury 2.60E‐04 8.54E‐07 3.74E‐06Nickel 2.10E‐03 6.90E‐06 3.02E‐05Selenium 2.40E‐05 7.88E‐08 3.45E‐07

Total HAP 1.89 0.006 0.03e AP‐42 Table 1.4‐3 "Emission Factors for Speciated Organic Compounds from Natural Gas Combustion" (7/98) and Table 1.4‐4 "Emission Factors for Metals from Natural Gas Combustion" (7/98).

g Emission Rate (ton/yr) = (Emission Rate, lb/hr) * (Annual Operation, hrs/yr) * (1 ton/2000 lb)

f Emission Rate (lb/hr) = (Emission Factor, lb/MMscf) * (Maximum Hourly Fuel Consumption, scf/hr) *

a AP‐42 Table 1.4‐1 "Emission Factors for Nitrogen Oxides (NOx) and Carbon Monoxide (CO) from Natural Gas Combustion" (7/98).b AP‐42 Table 1.4‐2 "Emission Factors for Criteria Pollutants and Greenhouse Gasses from Natural Gas Combustion" (7/98).

Potential Emissions per engine


c Emission Rate (lb/hr) = (Emission Factor, lb/MMscf) * (Maximum Hourly Fuel Consumption, scf/hr) * (MM/1,000,000)

3.35 MMBtu/hr Boiler Great Lakes Gas Transmission Thief River Falls Compressor Station No. 2



Emission Unit No. EQUI 4 (formerly EU4)Unit ID No.: 0Description of Unit: Natural gas‐fired boiler


Pollutant

Uncontrolled

Emission


Emissions

(lb/hr)

Emissions

(TPY)

Global

Warming

Potential

(GWP)[2]

CO2e

Emissions

(lb/hr)

CO2e

Emissions

(TPY)

CO2 53.06 kg CO2/MMBtu 391.87 1716.41 1 391.87 1716.41

CH4 0.001 kg CH4/MMBtu 0.0074 0.0323 25 0.18 0.81

N2O 0.0001 kg N2O/MMBtu 0.0007 0.0032 298 0.22 0.96

TOTAL GHGs ‐‐ ‐‐ 391.88 1716.44 ‐‐ ‐‐ ‐‐TOTAL GHGs (CO2e) ‐‐ ‐‐ ‐‐ ‐‐ ‐‐ 392.28 1718.18



Where: EFGHG =

Heat Input = Btu/hp‐hr x Site‐rated hp x (1 MMBtu/1,000,000 Btu) = MMBtu/hr

GWP = Global Warming Potentials, 40 CFR 98, Subpart A, Table A‐1


Fuel‐specific default CO2, CH4, or N2O emission factors from Table C‐1 for CO2 (Natural gas ‐



Emission Unit No. Insignificant ActivitiesUnit ID No.Description of Unit Three 0.2 MMBtu/hr Natural gas‐fired space heatersManufacturer ReznorDate of Construction/Modification 1997Fuel Used Natural GasMaximum Higher Heating Value (HHV) 1,020 Btu/scfHeat Input (MMBtu/hr) 0.6 MMBtu/hr Total of all three 0.20 mmBTU heatersMaximum Hourly Fuel Consumption 588 scf/hr

Annual Hours of Operation 8,760 hr/yrAnnual Fuel Consumption 5.15 MMscf/yr

Emission Factors:

Pollutant Emission Factor

(lb/MMscf)

Emission

Factor Source

NOx 100 aCO 84 aNM/NE VOC 5.5 b

PM10 7.6 b

PM2.5 7.6 bSO2 0.6 bLead 0.0005 b



(lb/hr)

Calculation

Methodology

Potential

Emissions d

(ton/yr) Potential (lb/hr)

NOx 0.06 c 0.26 515.3CO 0.05 c 0.22 432.8VOC 0.003 c 0.01 28.3PM10 0.004 c 0.02 39.2PM2.5 0.004 c 0.02 39.2SO2 0.0004 c 0.002 3.1Lead 0.0000003 c 1.29E‐06 0.0

Sample Calculation:

a AP‐42 Table 1.4‐1 "Emission Factors for Nitrogen Oxides (NOx) and Carbon Monoxide (CO) from Natural Gas Combustion" (7/98).b AP‐42 Table 1.4‐2 "Emission Factors for Criteria Pollutants and Greenhouse Gasses from Natural Gas Combustion" (7/98).

c Emission Rate (lb/hr) = (Emission Factor, lb/MMBtu) * (Maximum Hourly Fuel Consumption, scf/hr) * (MM/1,000,000)d Emission Rate (ton/yr) = (Emission Rate, lb/hr) * (Annual Operation, hrs/yr) * (1 ton/2000

3 Reznor Heaters Great Lakes Gas Transmission Thief River Falls Compressor Station No. 2



Emission Unit No. Insignificant ActivitiesHAP Calculated Emissions:

Emission Factor

Pollutant (lb/MMscf)e (lb/hr)f (tons/yr)g

HAPs:

2‐Methylnaphthalene 2.40E‐05 1.41E‐08 6.18E‐083‐Methylchloranthrene 1.80E‐06 1.06E‐09 4.64E‐097,12‐Dimethylbenz(a)anthracene 1.60E‐05 9.41E‐09 4.12E‐08Acenaphthene 1.80E‐06 1.06E‐09 4.64E‐09Acenaphthylene 1.80E‐06 1.06E‐09 4.64E‐09Anthracene 2.40E‐06 1.41E‐09 6.18E‐09Benz(a)anthracene 1.80E‐06 1.06E‐09 4.64E‐09Benzene 2.10E‐03 1.24E‐06 5.41E‐06Benzo(a)pyrene 1.20E‐06 7.06E‐10 3.09E‐09Benzo(b)fluoranthene 1.80E‐06 1.06E‐09 4.64E‐09Benzo(g,h,i)perylene 1.20E‐06 7.06E‐10 3.09E‐09Benzo(k)fluoranthene 1.80E‐06 1.06E‐09 4.64E‐09Chrysene 1.80E‐06 1.06E‐09 4.64E‐09Dibenzo(a,h)anthracene 1.20E‐06 7.06E‐10 3.09E‐09Dichlorobenzene 1.20E‐03 7.06E‐07 3.09E‐06Fluoranthene 3.00E‐06 1.76E‐09 7.73E‐09Fluorene 2.80E‐06 1.65E‐09 7.21E‐09Formaldehyde 7.50E‐02 4.41E‐05 1.93E‐04Indeno(1,2,3‐c,d)pyrene 1.80E‐06 1.06E‐09 4.64E‐09n‐Hexane 1.80E+00 1.06E‐03 4.64E‐03Naphthalene 6.10E‐04 3.59E‐07 1.57E‐06PAH 2.14E‐05 1.26E‐08 5.51E‐08Phenanthrene 1.70E‐05 1.00E‐08 4.38E‐08Pyrene 5.00E‐06 2.94E‐09 1.29E‐08Toluene 3.40E‐03 2.00E‐06 8.76E‐06Arsenic 2.00E‐04 1.18E‐07 5.15E‐07Beryllium 1.20E‐05 7.06E‐09 3.09E‐08Cadmium 1.10E‐03 6.47E‐07 2.83E‐06Chromium 1.40E‐03 8.24E‐07 3.61E‐06Cobalt 8.40E‐05 4.94E‐08 2.16E‐07Manganese 3.80E‐04 2.24E‐07 9.79E‐07Mercury 2.60E‐04 1.53E‐07 6.70E‐07Nickel 2.10E‐03 1.24E‐06 5.41E‐06Selenium 2.40E‐05 1.41E‐08 6.18E‐08

Total HAP 1.89 0.001 0.005

f Emission Rate (lb/hr) = (Emission Factor, lb/MMscf) * (Maximum Hourly Fuel Consumption, scf/hr) * g Emission Rate (ton/yr) = (Emission Rate, lb/hr) * (Annual Operation, hrs/yr) * (1 ton/2000

Potential Emissions for all three

heaters

e AP‐42 Table 1.4‐3 "Emission Factors for Speciated Organic Compounds from Natural Gas Combustion" (7/98) and Table 1.4‐4 "Emission Factors for Metals from Natural Gas Combustion" (7/98).

3 Reznor Heaters Great Lakes Gas Transmission Thief River Falls Compressor Station No. 2

Natural Gas

External

Combustion

HAP Emission FactorEmission

Factor

Emission

Factor

Emission

Factor

Emission

Factor

(lbs/MMBtu) (lbs/MMBtu) (lbs/MMBtu) (lbs/MMBtu) (lbs/MMscf)

1,1,2,2‐Tetrachloroethane 6.63E‐05 4.00E‐05 2.53E‐051,1,2‐Trichloroethane 5.27E‐05 3.18E‐05 1.53E‐051,3‐Butadiene 8.20E‐04 2.67E‐04 6.63E‐04 4.3E‐071,3‐Dichloropropene 4.38E‐05 2.64E‐05 1.27E‐052,2,4‐Trimethylpentane 8.46E‐04 2.50E‐042‐Methylnaphthalene 2.14E‐05 3.32E‐05 2.4E‐053‐Methylchloranthrene 1.8E‐067,12‐Dimethylbenz(a)anthracene 1.6E‐05Acenaphthene 1.33E‐06 1.25E‐06 1.8E‐06Acenaphthylene 3.17E‐06 5.53E‐06 1.8E‐06Acetaldehyde 7.76E‐03 8.36E‐03 2.79E‐03 4.0E‐05Acrolein 7.78E‐03 5.14E‐03 2.63E‐03 6.4E‐06Anthracene 7.18E‐07 2.4E‐06Benz(a)anthracene 3.36E‐07 1.8E‐06Benzene 1.94E‐03 4.40E‐04 1.58E‐03 1.2E‐05 2.1E‐03Benzo(a)pyrene 5.68E‐09 1.2E‐06Benzo(b)fluoranthene 8.51E‐09 1.66E‐07 1.8E‐06Benzo(e)pyrene 2.34E‐08 4.15E‐07Benzo(g,h,i)perylene 2.48E‐08 4.14E‐07 1.2E‐06Benzo(k)fluoranthene 4.26E‐09 1.8E‐06Biphenyl 3.95E‐06 2.12E‐04Carbon Tetrachloride 6.07E‐05 3.67E‐05 1.77E‐05Chlorobenzene 4.44E‐05 3.04E‐05 1.29E‐05Chloroform 4.71E‐05 2.85E‐05 1.37E‐05Chrysene 6.72E‐07 6.93E‐07 1.8E‐06Dibenzo(a,h)anthracene 1.2E‐06Dichlorobenzene 1.2E‐03Ethylbenzene 1.08E‐04 3.97E‐05 2.48E‐05 3.2E‐05Ethylene Dibromide 7.34E‐05 4.43E‐05 2.13E‐05Fluoranthene 3.61E‐07 1.11E‐06 3.0E‐06Fluorene 1.69E‐06 5.67E‐06 2.8E‐06Formaldehyde 5.52E‐02 5.28E‐02 2.05E‐02 7.1E‐04 7.5E‐02Indeno(1,2,3‐c,d)pyrene 9.93E‐09 1.8E‐06Methanol 2.48E‐03 2.50E‐03 3.06E‐03Methylene Chloride 1.47E‐04 2.00E‐05 4.12E‐05n‐Hexane 4.45E‐04 1.11E‐03 1.8E+00

Naphthalene 9.63E‐05 7.44E‐05 9.71E‐05 1.3E‐06 6.1E‐04PAH 1.34E‐04 2.69E‐05 1.41E‐04 2.2E‐06 2.1E‐05Perylene 4.97E‐09Phenanthrene 3.53E‐06 1.04E‐05 1.7E‐05Phenol 4.21E‐05 2.40E‐05Propylene Oxide 2.9E‐05Pyrene 5.84E‐07 1.36E‐06 5.0E‐06Styrene 5.48E‐05 2.36E‐05 1.19E‐05Tetrachloroethane 2.48E‐06Toluene 9.63E‐04 4.08E‐04 5.58E‐04 1.3E‐04 3.4E‐03Vinyl Chloride 2.47E‐05 1.49E‐05 7.18E‐06

2‐Stroke Lean‐

Burn Engines

4‐Stroke Lean‐

Burn Engines

4‐Stroke Rich‐

Burn Engines

Natural

Gas

Turbines

Xylene 2.68E‐04 1.84E‐04 1.94E‐04 6.4E‐05Arsenic 2.0E‐04Beryllium 1.2E‐05Cadmium 1.1E‐03Chromium 1.4E‐03Cobalt 8.4E‐05Manganese 3.8E‐04Mercury 2.6E‐04Nickel 2.1E‐03Selenium 2.4E‐05

Total HAPs 0.080 0.072 0.032 0.0010 1.8880

Natural Gas‐Fired Engines from AP‐42 Section 3.2 (7/00) [2SLB: Table 3.2‐1, 4SLB: Table 3.2‐2, 4SRB: Table 3.2‐3]Natural Gas‐Fired Turbines from AP‐42 Section 3.1‐3 (4/00)External Natural Gas Combustion from AP‐42 1.4‐3 (7/98)External Natural Gas Combustion, Metals from AP‐42 1.4‐4 (7/98)

Attachment 2: Subject Item Inventory and facility requirements

Agency Interest Name Subject Item ID SI Designation and Description

Great Lakes GasTransmission - Station2

ACTV1NullAll IA's

AISI1835NullNull

EQUI1EU001Unit 201

EQUI2EU003Standby Electrical Generator

EQUI3EU002Unit 202

EQUI4Null3.5 MMBtu/hr Natural Gas-FiredBoiler

STRU1BG001Unit 201 Building


STRU3BG003Service Building

STRU4SV003Standby Electrical Generator Stack

STRU5SV001Unit 201 stack

STRU6 SV002Unit 202 stack

List of SIs

Agency Interest: Great Lakes Gas Transmission -Station 2Agency Interest ID: 1835Activity: IND20130001 (Part 70 Reissuance)

Details for:SI Category: NoneSI Type: All

Agency Interest Name Subject Item ID SI Designation and DescriptionGreat Lakes GasTransmission - Station2



STRU7Null3.5 mmBTU NG Boiler

TFAC108900012Great Lakes Gas Transmission -Station 2

List of SIs

Agency Interest: Great Lakes Gas Transmission -Station 2Agency Interest ID: 1835Activity: IND20130001 (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

Great Lakes GasTransmission -Station 2

IND20130001 Activity Insignificant Air Emissions Activity ACTV1 NullAll IA's

Active /Existing

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

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

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

Minn. R. 7008.4100

Insignificant air emissions activity

Agency Interest: Great Lakes Gas Transmission - Station 2Agency Interest ID: 1835Activity: IND20130001 (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 Boiler EQUI4 Null 3.5 MMBtu/hr NaturalGas-Fired Boiler

1,2-Dichloroethane

2-Methylnaphthalene

3-Methylcholanthrene

7,12-Dimethylbenz[a]anthracene

Acenaphthene

Acenaphthylene

Anthracene

Arsenic compounds

Benzene

Benzo(a)anthracene

Benzo(b)fluoranthene

Benzo(ghi)perylene

Benzo(k)fluoranthene

Benzo[a]pyrene

Beryllium Compounds

Cadmium compounds

Carbon Dioxide

Carbon Dioxide Equivalent

Carbon Monoxide

Chromium compounds

Chrysene

Cobalt compounds

Dibenz[a,h]anthracene

Fluoranthene

Fluorene

Formaldehyde

HAPs - Single

HAPs - Total

Hexane

Indeno(1,2,3-cd)pyrene

Manganese compounds

Mercury Compounds

Methane

Naphthalene

Nickel compounds

Nitrogen Oxides

Nitrous Oxide

Particulate Matter

Phenanthrene

PM < 2.5 micron

PM < 10 micron

Pyrene

Selenium compounds

Sulfur Dioxide

Toluene

Total Polycyclic aromatic hydrocarbons

Volatile Organic Compounds

Reciprocating IC EngineEQUI2 EU003 Standby ElectricalGenerator

1,1,2-Trichloroethane

1,1,2,2-Tetrachloroethane

1,2-Dibromoethane (Ethylene dibromide); E..

1,3-Butadiene

1,3-Dichloropropene

Acetaldehyde

Acrolein

Benzene

Carbon Dioxide


Carbon Monoxide

Carbon tetrachloride

Chlorobenzene (Monochlorobenzene)

Chloroform

Dichloromethane (Methylene chloride)

Ethylbenzene

Formaldehyde

HAPs - Single

HAPs - Total

Methane

Methanol

Naphthalene

Nitrogen Oxides

Nitrous Oxide

Particulate Matter

0.083.08e-074.89e-05

0.013.45e-077.19e-08

0.110.11

2.45e-070.11

0.00321.44

3.02e-058.78e-06

0.033.74e-065.47e-062.59e-080.02590.02720.001080.001084.03e-084.32e-081.73e-081.21e-062.59e-082.01e-05

1.211,7181,716

1.58e-051.73e-071.73e-082.59e-081.73e-082.59e-082.59e-083.02e-052.88e-063.45e-082.59e-082.59e-082.3e-072.59e-083.45e-071.73e-05

0.083.08e-074.89e-05

0.013.45e-077.19e-08

0.110.11

2.45e-070.11

0.00321.44

3.02e-058.78e-06

0.033.74e-065.47e-062.59e-080.02590.02720.001080.001084.03e-084.32e-081.73e-081.21e-062.59e-082.01e-05

1.21

1,7161.58e-051.73e-071.73e-082.59e-081.73e-082.59e-082.59e-083.02e-052.88e-063.45e-082.59e-082.59e-082.3e-072.59e-083.45e-071.73e-05

0.027.03e-081.12e-050.002

7.88e-081.64e-08

0.020.02

5.58e-080.02

0.00070.33

6.9e-062e-060.01

8.54e-071.25e-065.91e-090.005910.0062

0.0002460.0002469.2e-099.85e-093.94e-092.76e-075.91e-094.6e-060.28

3923.61e-063.94e-083.94e-095.91e-093.94e-095.91e-095.91e-096.9e-066.57e-077.88e-095.91e-095.91e-095.25e-085.91e-097.88e-083.94e-06

0.001919.89

0.0008510.02680.020.2840.180.18

0.0002170.0003610.000120.0001130.00015532.591,0261,0250.01380.0230.0244

0.0001110.005810.0001870.0002220.000134

0.001919.89

0.0008510.02680.020.2840.180.18

0.0002170.0003610.000120.0001130.00015532.59

1,0250.01380.0230.0244

0.0001110.005810.0001870.0002220.000134

0.00044.54

0.0001940.00612

00.06480.0410.041

4.96e-058.24e-052.74e-052.58e-053.54e-05

7.44

2340.003160.005260.005582.54e-050.001334.26e-055.06e-053.06e-05

PTE by subject item

Agency Interest: NoneAgency Interest ID: 1835Activity: 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 Reciprocating IC EngineEQUI2 EU003 Standby ElectricalGenerator

Nitrous Oxide

Particulate Matter

PM < 2.5 micron

PM < 10 micron

Styrene

Sulfur Dioxide

Toluene


Vinyl chloride (chloroethene)


Xylenes, Total

Turbine EQUI1 EU001 Unit 201 1,3-Butadiene

Acetaldehyde

Acrolein

Benzene

Carbon Dioxide


Carbon Monoxide

Ethylbenzene

Formaldehyde

HAPs - Single

HAPs - Total

Methane

Naphthalene

Nitrogen Oxides

Nitrous Oxide

Particulate Matter

PM < 2.5 micron

PM < 10 micron

Propylene oxide

Sulfur Dioxide

Toluene



Xylenes, Total

EQUI3 EU002 Unit 202 1,3-Butadiene

Acetaldehyde

Acrolein

Benzene

Carbon Dioxide


Carbon Monoxide

Ethylbenzene

Formaldehyde

HAPs - Single

HAPs - Total

Methane

Naphthalene

Nitrogen Oxides

Nitrous Oxide

Particulate Matter

PM < 2.5 micron

PM < 10 micron

Propylene oxide

Sulfur Dioxide

Toluene



Xylenes, Total

0.00170.26

6.29e-050.001240.004890.01

0.0001040.170.170.17

0.00170.26

6.29e-050.001240.004890.01

0.0001040.170.170.17

0.0003880.06

1.44e-050.0002820.001120.001

2.38e-050.040.040.04

0.05831.910.0020.1180.0020.02646.016.016.010.18

206.810.001181.810.9360.6470.6470.0292511.2896,01395,9140.01090.005830.0364

0.000392

0.05831.910.0020.1180.0020.02646.016.016.010.18

206.810.001181.810.9360.6470.6470.0292511.28

95,9140.01090.005830.0364

0.000392

0.01330.44

0.0004580.0270.00050.006031.371.371.370.0447.22

0.000270.410.2140.1480.148

0.00666116.73

21,8980.00250.001330.008328.94e-05

0.05181.7

0.001780.1050.0020.02355.345.345.340.16

215.170.001051.610.8320.5750.5750.0259442.1685,34585,2570.009720.005180.0324

0.000348

0.05181.7

0.001780.1050.0020.02355.345.345.340.16

215.170.001051.610.8320.5750.5750.0259442.16

85,2570.009720.005180.0324

0.000348

0.01180.39

0.0004070.0240.00050.005361.221.221.220.0449.12

0.000240.370.190.1310.131

0.00592100.95

19,4650.002220.001180.00747.95e-05

PTE by subject item



Subject ItemCategoryDescription

Subject Item TypeDescription Subject Item ID SI Designation and Description Relationship

Related SubjectItem ID

Related Subject ItemType Description

Start Date (RelatedSubject Item)

End Date (RelatedSubject Item)

Equipment Boiler EQUI4Null3.5 MMBtu/hr Natural Gas-Fired Boil..

sends to STRU7 Stack/Vent 10/1/2008 Null

Reciprocating ICEngine

EQUI2EU003Standby Electrical Generator


Turbine EQUI1EU001Unit 201


EQUI3EU002Unit 202


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 EQUI1EU001Unit 201

Rolls Royce Avon 101G 18000 horsepower each Energy 11/1/1971 11/1/1971 Null

EQUI3EU002Unit 202

Rolls Royce Avon 76G 16000 horsepower each Energy 1/1/1972 1/1/1972 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

Boiler EQUI4Null3.5 MMBtu/hr Natural Gas-Fired Boi..

York-ShipleySPWFV-80-N93273

3.5million Britishthermal units

hours Heat 10/1/2008 10/1/2008 Null

Reciprocating IC EngineEQUI2EU003Standby Electrical Generator

Waukesha Motor Co F1197G 250 horsepower each Energy 11/1/1970 11/1/1971 Null

Emission Units 2


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

Subject Item TypeDescription Subject Item ID SI Designation and Description

FiringMethod Engine Use

EngineDisplacement

EngineDisplacementUnits

Subject toCSAPR?

ElectricGeneratingCapacity(MW)

Boiler EQUI4Null3.5 MMBtu/hr Natural Gas-Fired Boi..

Not coalburning

Null Null Null N Null

Reciprocating IC EngineEQUI2EU003Standby Electrical Generator

SI-4SRB Unlimited use 19.6 liters per cylinderNull Null

Emission Units 2 (continued)


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

Subject ItemTypeDescription Subject Item ID SI Designation and Description Height

Units(height) Length

Units(length) Width

Units(width)

Building STRU1BG001Unit 201 Building

33.75 feet 62.83 feet 43 feet


35.6 feet 66.2 feet 48 feet

STRU3BG003Service Building

20.6 feet 65 feet 40 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 STRU4SV003Standby Electrical Generator Stack

13.5 0.42 Null Null 3000 800 Estimate Horizontally


36 10.2 Null Null 236833 839 ManufacturerUpwards with no cap onstack/vent


40.75 11.3 Null Null 198688 766 ManufacturerUpwards with no cap onstack/vent

Stack/Vent, General


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

Documents

Draft Air Emission Permit No. 08900012- 101 1. 1 · Draft Air Emission Permit No. 08900012- 101. This technical support document (TSD) is intended for all parties interested in the