Technical Support Document for Draft Air Emission Permit ... - 12300070-101... · tank truck loading racks with vapor collection systems and vapor combustion units (VCUs), and insignificant

Technical Support Document, Permit Number: 12300070-101 Page 1 of 9

Technical Support Document for

Draft Air Emission Permit No. 12300070-101 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: 4613 - Refined Petroleum Pipelines)

Teri Holmes 1 Williams Center MD 27 Tulsa, Oklahoma 74172

Magellan Pipeline Co LP - Saint Paul Terminal 2451 W County Road C Roseville, MN 55113

Contact: Teri Holmes Phone: 918-574-7131

1.2 Facility description

Magellan Pipeline Company, L.P., owns and operates a liquid petroleum bulk storage terminal and interstate pipeline facility in Roseville, Minnesota. The facility consists of storage tanks, electric pumps stations, two tank truck loading racks with vapor collection systems and vapor combustion units (VCUs), and insignificant emission units. The terminal receives and transports petroleum and biofuel products to other terminals through an interstate pipeline distribution network. Volatile organic compounds (VOCs) are the primary pollutant emitted from the facility, including volatile hazardous air pollutants (HAPs). Most VOCs and HAPs emissions are the two truck loading racks’ emissions that are collected but uncombusted by the two VCUs, with a smaller percentage of emissions going uncollected from the loading racks. Additional emissions are from storage tank standing and working losses; tank floating roof landing events; and fugitive emissions from valves, pumps, and flanges.

1.3 Description of the activities allowed by this permit action This permit action is Part 70 Reissuance.

1.4 Description of notifications and applications included in this action

Table 2. Notifications and applications included in this action

Date received Application/Notification type and description 07/06/2010 Part 70 Reissuance (IND20100001)

11/3/2008 Part 70 Permit Reopening – an initial notification for 40 CFR pt. 63, subp. BBBBBB (IND20080001)


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 0.012 0.009 0.003 0.001 28.2 70.3 190 306 4.88 15.9 Total facility actual emissions (2015) 0.00 0.00 0.00 0.00 10.1 25.4 * 101 *

*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 has been updated to reflect current MPCA templates and standard citation formatting. · The TK/EU, CE, SV, and GP identifiers have been updated to EQUI, TREA, STRU, and COMG, respectively,

to reflect MPCA’s current permitting practice. · Some requirements have been reordered to help with clarity (i.e., similar requirements are grouped). · Data on the site’s Aboveground Storage Tanks (ASTs), VCUs, stacks, and buildings has been updated

based on the 2015 permit reissuance application, 2017 site visit, and 2017 supplemental information. · Performance testing frequency for Tank Truck Bottom Load MPL with Vapor Combustor Control has

been changed from previous 60 month frequency to 36 month frequency. · New Source Performance Standard (NSPS) for Storage Vessels for Petroleum Liquids (40 CFR pt. 60,

subp. Ka) requirements that had applied to EQUI 38, 40, 69, 77, and 80 (TK020, TK027, TK019, TK029, and TK032, respectively) in previous GP001 have been broken out to each individual tank for easier compliance.

· NESHAP for Source Category: Gasoline Distribution Bulk Terminals, Bulk Plants, and Pipeline Facilities (40 CFR pt. 63, subp. BBBBBB) requirements have been incorporated into this permit for COMG 3, which includes the loading racks (EQUI 19 and 20), VCUs (TREA 6 and 7), and all ASTs containing gasoline.

· TREA 6 and 7 (formerly CE001 and CE002) were changed from flares to other control equipment to better characterize the control equipment.

· The ASTs potential to emit was updated with new numbers from TankESP (done using Reid Vapor Pressure (RVP) 13 gasoline since the facility noticed an upward trend in annualized RVP of the gasoline). See section 3.1.2 for more information on TankESP. To accurately permit the facility for emissions, AST capacities and the RVP were modified in TankESP and the facility submitted revised emissions data.

· Floating roof landing emissions were incorporated into the AST potential. · Railcar, butane, and biodiesel off-loading stations were added as insignificant activities under Minn. R.

7007.1300, subps. 4 and 3(I). Railcar and butane off-loading were started prior to the first pt. 70 permit reissuance but were not accounted for. Biodiesel off-loading was installed in 2005, considered to be insignificant at the time, and added as an insignificant activity.


· Tank 951 was removed from the insignificant activities because it is permanently decommissioned. · Tank 904 was removed from the insignificant activities because its potential to emit VOCs is greater than

2,000 pounds per year, so it is considered an emission unit. · Portable water treatment equipment, including, but not limited to, air stripper, carbon filter units, and

chemical/biological units, was removed from the insignificant activities list because it is no longer on site.

· SIC code 5171 (Petroleum Bulk Stations and Terminals) was removed from permit. Magellan Pipeline Company, L.P., determined that because they do not own the product, they are not a 5171 facility.

2. Regulatory and/or statutory basis

2.1 New source review (NSR)

The facility is an existing major source under New Source Review regulations (40 CFR § 52.21), because it is one of the 28 listed source categories for NSR with potential VOCs exceeding 100 tpy. Even if the facility were not a listed source category it would be a major source with potential VOCs exceeding 250 tpy. 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 facility is subject to Standards of Performance for Bulk Gasoline Terminals (40 CFR pt. 60, subp. XX). The VCUs are used to meet 40 CFR pt. 60, subp. XX, and were previously described as flares. However, the VCUs operate different than flares, so they are not subject to the flare requirements in 40 CFR pt. 60, subp. A (General Requirements). This is detailed in Attachment 4, a U.S. Environmental Protection Agency (EPA) Applicability Determination Letter. Flare-specific requirements were removed from the VCUs and their emission unit types were changed from flares to other control equipment. While the EPA Applicability Determination Letter states that VCUs operate more similarly to thermal oxidizers than flares, due to their monitoring parameters VCUs are a unique type of control that is best categorized as other control equipment. Five ASTs at the facility (EQUI 38, 40, 69, 77, and 80) are also subject to Standards of Performance for Storage Vessels for Petroleum Liquids for Which Construction, Reconstruction, or Modification Commenced after May 18, 1978, and prior to July 23, 1984 (40 CFR pt. 60, subp. Ka). See Table 6 for the rationale of applying 40 CFR pt. 60, supb. XX to the facility and 40 CFR pt. 60, subp. Ka to the five ASTs.

2.4 National emission standards for hazardous air pollutants (NESHAP) The facility is an existing area source of HAPs and is subject to 40 CFR pt. 63, subp. BBBBBB (NESHAP for Source Category: Gasoline Distribution Bulk Terminals, Bulk Plants, and Pipeline Facilities) because it is a pipeline distribution bulk terminal as defined in 40 CFR § 63.11081(a)(1). All 22 gasoline-storing ASTs at the facility, the 2 loading racks (EQUI 19 and 20), and the 2 VCUs (TREA 6 and 7) are subject to the requirements relating to this NESHAP, so the requirements are listed under COMG 3.

2.5 Compliance assurance monitoring (CAM) Table 5 below lists the sources subject to CAM, the control equipment used, whether the source is a large or other pollutant specific emission unit (PSEU), and the pollutants triggering CAM.


Table 5. CAM summary

Unit Control CAM applicability Pollutant EQUI 19 TREA 6 VCU Other VOC EQUI 20 TREA 7 VCU Other VOC

For other PSEUs (not large), records must be made at a minimum of once per 24 hours. See Attachment 3 to this document for the CAM plan submitted by the applicant for their first permit reissuance in 2002.

2.6 Minnesota State Rules The facility is not subject to Minnesota Standards of Performance. Table 6. Regulatory overview of facility

Subject item* Applicable regulations Rationale COMG 3 - Aboveground Storage Tanks storing gasoline, loading racks transferring gasoline, and VCUs controlling gasoline off-gassing

40 CFR pt. 63, subp. BBBBBB NESHAP for Source Category: Gasoline Distribution Bulk Terminals, Bulk Plants, and Pipeline Facilities. This facility distributes liquid petroleum products through a distribution bulk terminal.

· The facility is an area source of HAPs. · The facility is defined as a bulk gasoline terminal that is

not subject to the control requirements of 40 CFR pt. 63, subp. R or subp. CC.

· The facility has a gasoline throughput of >250,000 gal/day.

· 22 of the tanks are >75 ft3: o 21 have internal floating roofs. o One is a surge tank.

EQUI 19 and EQUI 20 - Loading-Unloading Equipment

40 CFR pt. 60, subp. XX

NSPS for Bulk Gasoline Terminals. This facility is a bulk gasoline terminal which delivers liquid product into gasoline tank trucks via loading racks. · The facility is defined as a bulk gasoline terminal. · The facility has a gasoline throughput of > 75,700

liters/day (19,998 gal/day). · The construction or refurbishment of the VCUs did not

commence prior to December 17, 1980. EQUI 38, EQUI 40, EQUI 69, EQUI 77, EQUI 80 - Aboveground Storage Tanks

40 CFR pt. 60, subp. Ka NSPS for Petroleum Liquids for which construction, reconstruction, or modification commenced after May 18, 1978, and prior to July 23, 1984. · The ASTs each have a storage capacity >40,000 gallons

that is used to store petroleum liquids. · The ASTs were modified after May 18, 1978, and prior to

July 23, 1984 (1981 when floating roofs were installed). · The ASTs had a physical change between May 18, 1978,

and July 23, 1984, that resulted in an increase in the emission rate of VOCs to the atmosphere (the subsequent storage of petroleum liquids with a higher true vapor pressure than originally stored).


Subject item* Applicable regulations Rationale TREA 6 and TREA 7 - 099-Other

40 CFR pt. 64 CAM for two ‘other’ PSEUs. · The facility is required to have a part 70 permit. · The facility is a major source of VOCs. · The PSEUs use control devices to achieve compliance with

the TOC emission limit. · The PSEUs have potential pre-control device emissions of

VOCs that are greater than 100% of the major source threshold for a NSR listed source category (100 tpy).

· The PSEUs have potential post-control device emissions of VOCs that are less than 100% of the major source threshold for a NSR listed source category (100 tpy).

*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 PTE calculations of the Facility, which contain detailed spreadsheets and supporting information prepared by the MPCA and the Permittee. The PTE calculations have been updated since the previous permit issuance. Emission equations, emission rates, and known physical properties are generally based on AP-42 Chapter 5.2, Transportation and Marketing of Petroleum Liquids, and Chapter 7.1, Organic Liquid Storage Tanks. Emission factors are cited within the attached calculation spreadsheets.

3.1.1 Tank Truck Bottom Loadings w/vapor collection and combustion controls

Evaporative emissions during the loading process are the primary source of VOC losses at the facility. 3.1.1.1 PTE calculations for VOC emissions from distillate loading at the loading racks incorporated the

vapor collection efficiency and assumed zero percent combustion efficiency for worst-case scenario emissions.

3.1.1.2 Emissions from ethanol loading are estimated as if it were gasoline, since gasoline is more volatile. PTE calculations for VOC emissions from gasoline and ethanol loading at the loading racks incorporated the vapor collection efficiency and, rather than a combustion efficiency, the enforceable emission limit from the NSPS for Bulk Gasoline Terminals (35 mg VOC per liter of gasoline loaded). This is a valid assumption because the loading rack systems shut down if the continuous monitoring equipment read measurements that exceed the federally enforceable limit.

3.1.2 Storage Tank Emission Calculations and Tank Roof Landing Emission Calculations

The previous PTE from ASTs was calculated using TANKS version 4.0. The PTE from the ASTs was updated using Tank Emissions Software Program (TankESP). TankESP applies the methodology of Chapter 7.1 of AP-42, Organic Liquid Storage Tanks. In TankESP it was assumed that gasoline had a vapor pressure of RVP 13 and that distillate fuels are jet kerosene. In 2007 EPA storage tank PTE calculations were updated to include the air emissions that result when floating roof landings are resting on roof landings. Accordingly, the facility’s PTE calculations were updated to include the emissions from the ASTs that have floating roofs (EQUI 38, 40, 41, 49, 50, 51, 52, 53, 54, 55, 56, 58, 59, 60, 61, 62, 63, 64, 65, 69, 77, 80). Floating roofs generally decrease emissions from ASTs by eliminating the interface between the stored liquid and ambient air (where evaporation occurs). Each AST with a floating roof has internal roof landing “legs” that keep the floating roof off the bottom if the AST is nearly empty. If the liquid level is lowered below the height of the floating roof landings, the roof will rest on the landings, rather than on the liquid, limiting the control efficiency of the floating roof. Emissions that occur during this period are referred to as floating roof landing emissions. The floating roof landing emissions were generated from TankESP, checked against calculations that used


equations from AP-42 Chapter 7.1, and combined with the standing and working loss emissions from the affected ASTs. The calculated PTE with TankESP and floating roof landing emissions is higher; therefore, the AST PTE summary was updated to reflect the increase in potential emissions. PTE calculations for additive tanks that qualify as insignificant activities were also updated.

3.1.3 Fugitive VOC Emission Calculations The VOC emissions were calculated using the Marketing Terminal Average Emission Factors from EPA Protocol for Equipment Leak Emission Estimates, EPA-453R/-95-017, November 1995, Table 2-3.

3.1.4 Hazardous Air Pollutants (HAP) Emission Calculations

HAP emission calculations were based on the HAP (specifically 2,2,4-trimethylpentane, benzene, ethyl benzene, hexane, toluene, and xylenes) content of gasoline vapors in Gasoline Distribution Industry (Stage I) - Background Information for Proposed Standards, November 1994 (EPA-453/R-94-002a). The HAP destruction efficiency of the vapor collection/destruction system is assumed to be equivalent to the VOC destruction efficiency. This is a reasonable assumption according to Control Technologies for HAP, EPA (625/6-91/014, June 1991).

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. Table 7 summarizes the monitoring 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 7 summarizes the monitoring requirements.


Table 7. Monitoring

Subject Item* Requirement (basis)

What is the monitoring? Why is this monitoring adequate?

EQUI 19, EQUI 20 Total Organic Compounds <= 35 milligrams per liter of gasoline loaded. Gauge pressure in delivery tank <= 4,500 pascals (NSPS, subp. XX)

Monthly leak inspections. Periodic TOC performance testing. Monitoring the gauge pressure to be less than 450 mm of water in the delivery tank on a continuous basis.

Monitoring the gauge pressure, recordkeeping (leak repairs and corrective actions), O&M records, and periodic TOC testing are indicators to have reasonable assurance of compliance.

TREA 6, TREA 7 Emissions shall not be vented to a VCU without its assist air blower on, vapor valve open, and pilot flame lit. (CAM)

Daily monitoring, monthly leak inspections, semi-annual VCU inspections, and annual calibrations. Periodic TOC performance testing.

The NSPS monitoring requirements of 40 CFR pt. 60, subp. XX, in addition to monitoring associated with 40 CFR pt. 63, subp. BBBBBB, and 40 CFR pt. 64 help to ensure compliance with the limits. Periodic TOC testing and recordkeeping (inspections, leak repairs, corrective actions, and O&M) are required to support compliance with NSPS and CAM requirements.

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

3.3 Performance Testing Requirements Previous permits required performance testing and set the performance test frequency at 60-month intervals. All tests performed since the last reissuance were in compliance. The results of the most recent performance testing were reviewed to inform this permit action. The testing results were reported in RE: Notice of Compliance for August 21-22, 2012, Performance Test on EU001 (Tank Truck Bottom Load MPL w/Vapor Combustor Control) and EU002 (Tank Truck Bottom Load – Flint Hills Resources (FHR) w/Vapor Combustor Control) Pursuant to Air Emission Permit Number 12300070-004; and Test Plan Approval Letter dated August 8, 2012. Table 8 contains the date of the most recent performance test with available data, TOC limits for each stack, the results from the testing, the percentage of the limit, and the performance test interval assigned (based on the percentage). The Permittee will conduct performance tests in August 2017. Since the data from the tests is not available at the time of notice, it was not used to inform this permit action. Table 8. 2012 Stack Testing Data

Unit Test Date Limit

(mg TOC/L gasoline loaded) Test Result

(mg/L) % of Limit

Performance Test Intervals (months)

EQUI 19 (TREA 6) 22 Aug 2012 35 30.1 86% 36 EQUI 20 (TREA 7) 21 Aug 2012 35 10.9 31% 60


3.4 Insignificant activities Magellan Pipeline Co LP - St Paul Terminal 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. It is our belief that IAs listed in Appendix A to the permit are associated with inconsequential environmental impacts and present little potential for violations of generally applicable requirements; therefore, no additional periodic monitoring will be required. Table 9 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 9. 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 <= 0.4 lb/MMBtu Opacity <= 20% with exceptions (Minn. R. 7011.0510)

For this unit, based on the fuels used and EPA published emissions factors, it is highly unlikely that it could violate the applicable requirements. No monitoring warranted. There is one natural gas furnace (203,000 Btu/hr).

Emissions from a laboratory, as defined in Minn. R. 7007.1300, subp. 3(G)

PM, variable depending on airflow Opacity <= 20% (Minn. R. 7011.0715)

These are small, intermittent operations that typically do not have any emissions. It is highly unlikely that they could violate the applicable requirements. No monitoring warranted.

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

PM, variable depending on airflow Opacity <= 20% (Minn. R. 7011.0715)

There are 22 fuel bulk additive storage tanks (2 @ ~500 gal, 1 @ 750 gal, 6 @ ~1,000 gal, 3 @ ~2,000 gal, 1 @ 3,000 gal, 2 @ ~4,000 gal, 4 @ ~6,000 gal, 1 @ 8,000 gal, 1 @ 10,000 gal, 1 @ ~12,000 gal), 2 biofuel storage tanks (128,490 gal each), and biodiesel unloading. Based on the fuels stored and unloaded, it is highly unlikely that the units could violate the applicable requirements. See PTE calculations for justification of VOC < 2,000 lb/yr. No monitoring warranted.

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 Facility is located in the Metro area and has paved parking lots and a few unpaved private roads. Nearly all surfaces are currently paved. There is minimal vehicle traffic on unpaved roads. No monitoring warranted.

Infrequent use of spray paint equipment for routine housekeeping or plant upkeep activities not associated with primary production processes at the stationary source

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

While painting operations have the potential to emit particulate matter, these particular activities are not associated with production, so they occur infrequently and outdoors. Testing or monitoring is not feasible.

Individual units with potential or actual emissions meeting the criteria in Minn. R. 7007.1300, subp. 4(A)-(D)

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

There is ethanol, railcar, and butane offloading. Based on fuel type, it is highly unlikely that the units could violate the applicable requirements. See PTE calculations for justification of VOC < 2.28 lb/hr PTE or VOC < 1 ton/yr actual, and HAP < 1 ton/yr actual. No monitoring warranted.


3.5 Permit organization The only item that deviates from MPCA Tempo Guidance for ordering and grouping of requirements is the listing of certain applicable requirements at the group level even though they apply at the individual unit. Specifically: 40 CFR pt. 63, subp. BBBBBB, is listed at COMG 3. In general, requirements that apply to individual pieces of equipment should be tracked at the unit level and should not be listed at a group. The main reason is if there were noncompliance with a requirement by one unit within the group, the computer system would say the whole group was out of compliance. For this case, the gasoline storage and loading equipment (COMG 3) are subject to monitoring, maintenance, and recordkeeping requirements that apply to all gasoline-loading equipment. If monitoring, maintenance, and/or recordkeeping are found to be noncompliant, it is likely that the noncompliance will have affected all gasoline-loading equipment rather than an individual unit. It is unlikely that the MPCA would need to track noncompliance with the requirements at the individual unit level, so the permit team decided that a group was an acceptable way to include these requirements.

3.6 Comments received This Section will be completed after the referenced review periods.

4. Permit fee assessment This permit action is the reissuance of an individual Part 70 permit with no rolled-in applications; therefore, no application fees apply under Minn. R. 7002.0016, subp. 1. The permit reopening to incorporate a new NESHAP is not a chargeable activity (i.e., the standard was not triggered by the modifications requested in the permit applications – it falls under a permit reopening being incorporated in the reissuance).

5. Conclusion Based on the information provided by Magellan Pipeline Co LP - Saint Paul Terminal the MPCA has reasonable assurance that the proposed operation of the emission facility, as described in the Air Emission Permit No. 12300070-101 and this TSD, will not cause or contribute to a violation of applicable federal regulations and Minnesota Rules. Staff members on permit team: Laura Lyons (permit engineer)

Adriane Lenshek (peer reviewer) Beckie Olson (permit writing assistant) Laurie O’Brien (administrative support) Brent Rohne (enforcement) Curtis Stock (stack testing)

TEMPO360 Activities: Part 70 Reissuance (IND20100001)

Attachments: 1. PTE summary calculation spreadsheets 2. Subject item inventory and facility requirements 3. Compliance Assurance Monitoring (CAM) plan 4. EPA VCU Applicability Determination

ATTACHMENT 1:

Emissions Summary Calculation Spreadsheets

Magellan Pipeline Company, L.P. - St. Paul Terminal MPL Loading Rack Data

Throughput and Loading InformationPotential Rack Throughput (1000 gallons/year) 840,960

Potential Gasoline Throughput (1000 gallons/year)1 420,480

Potential Kerosene Throughput (1000 gallons/year)1 420,480

No. of Spots at Loading Rack 4

Percent of Loading that is Balanced 100%

Percent of Loading that is Normal (not balanced) 0%

Physical PropertiesTemperature of Bulk Liquid Loaded (oF)2

44.70

Saturation Factor (S) 1.00

Molecular Weight of Gasoline RVP 13 vapors362.00

Molecular Weight of Kerosene Vapors4130.00

Avg. True Vapor Pressure of Gasoline RVP 13 (psia)35.2100

Avg. True Vapor Pressure of Kerosene (psia)5 0.0049

Vapor Control SpecificationsVapor Control Type VCU

Distillate Emissions considered uncontrolled (no destruction--worst case) 0.000Vapor Collection Efficiency6

0.987

Emission Limits--VCUEnforceable limit7 for gasoline loading (mg-VOC/liter-loaded) 35.00

Sources:

2. TanksESP program, noted in header portion of print-out

3. AP-42 Table 7.1-2. Properties of Gasoline RVP 13

4. AP-42 Table 7.1-2. Properties of Jet kerosene5. TanksESP program, based on ATVP for kerosene and distillate at Tbulk

6. EPA AP-42 page 5.2-6

7. 40 Code of Federal Regulations subpart XX [60.502(b)]

1. Total throughput is for 4 LR spots, 2 for gasoline and 2 for kerosene. Maximum throughput for eithersubstance is half of total.

Magellan Pipeline Company, L.P. - St. Paul Terminal Potential to Emit - MPL Loading Rack

Loading Loss Factor: LL = 12.46*SPM/T 1

Gasoline &

Ethanol 2 DistillateSaturation Factor S 1.00 1.00 Gasoline Distillate TotalLoading Temperature T, (oR) 504.37 504.37 2,2,4 Trimethylpentane 0.008 0.666 0.026 0.692Avg. True Vapor Pressure P (psia) 5.2100 0.0049 Benzene 0.009 0.749 0.030 0.779Vapor Molecular Weight M 62.00 130.00 Ethyl Benzene 0.001 0.083 0.003 0.087Loading Loss Factor LL (lb/1000-gal) 7.980 0.016 Hexane 0.016 1.332 0.053 1.384

Toluene 0.013 1.082 0.043 1.125Potential Uncontrolled VOC Emissions = LL*Q Total Xylenes 0.005 0.416 0.017 0.433

Gasoline &

Ethanol 2 Distillate Totals Total HAP 0.052 4.327 0.172 4.499Throughput Q, (1000-gal/yr) 420,480 420,480

lb/yr 3,355,394 6,617 3,362,011ton/yr 1,678 3 1,681

Gasoline &

Ethanol 2 Distillate TotalsVapor Collection Efficiency 0.987 0.987Estimate VCU Stack Emissions Using 1. Combustion Efficiency, or2. Emission Limit? 2 1Quantity of Vapor Collected (tpy) 1,655.89 3.27

Vapor Combustion Efficiency 3 N/A 0.000Enforceable Emission Limit (mg/l) 35.000 N/AUncaptured VOC Emissions (ton/yr) 21.810 0.043 21.85Uncombusted VOC Emissions (ton/yr) 61.409 3.265 64.67Total VOC Emissions (ton/yr) 83.219 3.308 86.53Uncombusted VOC Emissions (lb/hr) 14.020 0.746 14.77Total VOC Emissions (lb/hr) 19.000 0.755 19.76

NOx Emission factor (mg/l burned)4

NOx Emissions (ton/yr) 7.018 7.018 14.04NOx Emissions (lb/hr) 1.602 1.602 3.20

CO Emission factor (mg/l burned)4

CO Emissions (ton/yr) 17.545 17.545 35.09CO Emissions (lb/hr) 4.006 4.006 8.01

NOTES1. Loading Loss Factor equation from AP-42 Chapter 5, Section 2: Transportation and Marketing of Petroleum Liquids, page 5.2-4.2. Because ethanol is blended with gasoline upon loading, emissions from ethanol loading are estimated as if it were gasoline.3. For gasoline, uncombusted VOC is estimated as 35 mg VOC per liter gasoline loaded. Therefore, vapor-combustion efficiency is N/A.4. Source of NOx and CO Emission factors: manufacturer's specifications.

HAP Emissions (ton/yr)

4

10

Potential Controlled VOC and Combustion Emissions

Fraction of VOCHazardous Air Pollutant

Magellan Pipeline Company, L.P. - St. Paul Terminal FHR Loading Rack Data

Throughput and Loading InformationPotential Rack Throughput (1000 gallons/year) 840,960

Potential Gasoline Throughput (1000 gallons/year)1 420,480

Potential Kerosene Throughput (1000 gallons/year)1 420,480

No. of Spots at Loading Rack 4

Percent of Loading that is Balanced 100%

Percent of Loading that is Normal (not balanced) 0%

Physical PropertiesTemperature of Bulk Liquid Loaded (oF)2

44.70

Saturation Factor (S) 1.00

Molecular Weight of Gasoline RVP 13 vapors362.00

Molecular Weight of Kerosene Vapors4130.00

Avg. True Vapor Pressure of Gasoline RVP 13 (psia)35.2100

Avg. True Vapor Pressure of Kerosene (psia)5 0.0049

Vapor Control SpecificationsVapor Control Type VCU

Distillate Emissions considered uncontrolled (no destruction--worst case) 0.000Vapor Collection Efficiency6

0.987

Emission Limits--VCUEnforceable limit7 for gasoline loading (mg-VOC/liter-loaded) 35.00

Sources:

2. TanksESP program, noted in header portion of print-out

3. AP-42 Table 7.1-2. Properties of Gasoline RVP 13

4. AP-42 Table 7.1-2. Properties of Jet kerosene5. TanksESP program, based on ATVP for kerosene and distillate at Tbulk

6. EPA AP-42 page 5.2-6

7. 40 Code of Federal Regulations subpart XX [60.502(b)]

1. Total throughput is for 4 LR spots, 2 for gasoline and 2 for kerosene. Maximum throughput for eithersubstance is half of total.

Magellan Pipeline Company, L.P. - St. Paul Terminal Potential to Emit - FHR Loading Rack


Gasoline &

Ethanol 2 DistillateSaturation Factor S 1.00 1.00 Gasoline Distillate TotalLoading Temperature T, (oR) 504.37 504.37 2,2,4 Trimethylpentane 0.008 0.666 0.026 0.692Avg. True Vapor Pressure P (psia) 5.2100 0.0049 Benzene 0.009 0.749 0.030 0.779Vapor Molecular Weight M 62.00 130.00 Ethyl Benzene 0.001 0.083 0.003 0.087Loading Loss Factor LL (lb/1000-gal) 7.980 0.016 Hexane 0.016 1.332 0.053 1.384

Toluene 0.013 1.082 0.043 1.125Potential Uncontrolled VOC Emissions = LL*Q Total Xylenes 0.005 0.416 0.017 0.433

Gasoline &

Ethanol 2 Distillate Totals Total HAP 0.052 4.327 0.172 4.499Throughput Q, (1000-gal/yr) 420,480 420,480

lb/yr 3,355,394 6,617 3,362,011ton/yr 1,678 3 1,681

Potential Controlled VOC and Combustion EmissionsGasoline &

Ethanol 2 Distillate TotalsVapor Collection Efficiency 0.987 0.987Estimate VCU Stack Emissions Using 1. Combustion Efficiency, or 2. Emission Limit? 2 1Quantity of Vapor Collected (tpy) 1,655.89 3.27

Vapor Combustion Efficiency 3 N/A 0.000Enforceable Emission Limit (mg/l) 35.000 N/AUncaptured VOC Emissions (ton/yr) 21.810 0.043 21.85Uncombusted VOC Emissions (ton/yr) 61.409 3.265 64.67Total VOC Emissions (ton/yr) 83.219 3.308 86.53Uncombusted VOC Emissions (lb/hr) 14.020 0.746 14.77Total VOC Emissions (lb/hr) 19.000 0.755 19.76

NOx Emission factor (mg/l burned)4

NOx Emissions (ton/yr) 7.018 7.018 14.04NOx Emissions (lb/hr) 1.602 1.602 3.20

CO Emission factor (mg/l burned)4

CO Emissions (ton/yr) 17.545 17.545 35.09CO Emissions (lb/hr) 4.006 4.006 8.01

NOTES1. Loading Loss Factor equation from AP-42 Chapter 5, Section 2: Transportation and Marketing of Petroleum Liquids, page 5.2-4.2. Because ethanol is blended with gasoline upon loading, emissions from ethanol loading are estimated as if it were gasoline.3. For gasoline, uncombusted VOC is estimated as 35 mg VOC per liter gasoline loaded. Therefore, vapor-combustion efficiency is N/A.4. Source of NOx and CO Emission factors: manufacturer's specifications.

4

10

Hazardous Air PollutantFraction of VOC

HAP Emissions (ton/yr)

Magellan Pipeline Company, L.P. - St. Paul Terminal Potential to Emit - MPL and FHR VCUs pilot light fuel

Operating Hours per Year

Fuel Usage per VCU

Natural Gas Emission Factors

hrs/yr scf/hr1 lb/MMscf2,3,4,5,6 lb/hr/VCU tpy/VCU lb/hr tpyNOx 100 0.02 0.08 0.04 0.16CO 84 0.02 0.07 0.03 0.13CO2 120000 22 95 43 189N2O 2.2 0.00 0.00 0.00 0.00CH4 2.3 0.00 0.00 0.00 0.00CO2e 120713 22 95 43 190PM 7.6 0.00 0.01 0.00 0.01

PM10 5.7 0.00 0.00 0.00 0.01PM2.5 1.9 0.00 0.00 0.00 0.00SO2 0.6 0.00 0.00 0.00 0.00VOC 5.5 0.00 0.00 0.00 0.01

Benzene 0.0021 0.00 0.00 0.00 0.00Hexane 1.8 0.00 0.00 0.00 0.00Toluene 0.0034 0.00 0.00 0.00 0.00

Total HAP 11.3 0.00 0.01 0.00 0.02

NOTES

Pollutant

VCU PTEVCUs Total PTE

(2 VCUs)

3. Source of CO2 EF: AP-42 Table 1.4-2: assumes approximately 100% conversion of fuel carbon to CO2.

8,760 180

6. Source of Benzene, Hexane, Toluene, and Total HAPs from AP-42 Table 1.4-3: Emission Factors for SpeciatedOrganic Compounds from Natural Gas Combustion.

5. CO2e EF calculated using the following equation: (CO2 EF) + (N2O EF)*(N2O global warming potential (GWP)) +(CH4 EF)*(CH4 GWP). Source of GWPs: 40 CFR pt. 98, subp. A, table A-1, Global Warming Potentials.

1. The pilot light fuel rate is 1-3 scf/min (manufacturer's specification), so assumed 3 scfm, or 180 scf/hr for 1 VCU.

2. Source of NOx and CO emission factors (EFs): AP-42 Table 1.4-1: Emission Factors for Nitrogen Oxides (NOx)and Carbon Monoxide (CO) from Natural Gas Combustion.

4. Source of N2O, CH4, PM, SO2, and VOC EFs: AP-42 Table 1.4-2: Emission Factors for Criteria Pollutants andGreenhouse Gases from Natural Gas Combustion.

Magellan Pipeline Company, L.P. - St. Paul Terminal Potential to Emit - Tanks Details

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

EQUI 49 425 (Rel TK 001 Gasoline 210,000 2 420,000 1,151 48 1,675.04 0.84 2.40 0.00 0.00 1,677.44 0.19 0.84EQUI 50 509 TK 002 Gasoline 420,420 104 43,723,680 119,791 4,991 2,726.51 1.36 171.80 0.09 285.83 0.14 3,184.14 0.36 1.59EQUI 51 510 TK 004 Gasoline 418,950 104 43,570,800 119,372 4,974 2,726.51 1.36 171.20 0.09 285.83 0.20 3,305.83 0.38 1.65EQUI 52 646 TK 003 Gasoline 656,712 104 68,298,048 187,118 7,797 3,281.14 1.64 214.68 0.11 408.13 0.14 3,781.65 0.43 1.89EQUI 53 649 TK 005 Gasoline 772,044 104 80,292,576 219,980 9,166 2,968.27 1.48 252.39 0.13 408.13 0.20 3,628.78 0.41 1.81EQUI 54 650 TK 006 Gasoline 772,380 104 80,327,520 220,075 9,170 2,999.17 1.50 252.50 0.13 408.13 0.20 3,659.80 0.42 1.83EQUI 55 717 TK 007 Gasoline 1,129,842 104 117,503,568 321,928 13,414 4,120.82 2.06 284.12 0.14 355.31 0.18 4,760.25 0.54 2.38EQUI 56 718 TK 008 Gasoline 1,128,204 104 117,333,216 321,461 13,394 4,120.82 2.06 283.71 0.14 355.31 0.18 4,759.84 0.54 2.38EQUI 58 719 TK 009 Gasoline 1,129,022 104 117,418,288 321,694 13,404 4,120.82 2.06 283.91 0.14 355.31 0.18 4,760.05 0.54 2.38EQUI 59 720 TK 010 Gasoline 1,130,094 104 117,529,776 321,999 13,417 4,120.82 2.06 284.18 0.14 355.31 0.18 4,760.32 0.54 2.38EQUI 60 743 TK 011 Gasoline 1,115,100 104 115,970,400 317,727 13,239 4,120.82 2.06 280.41 0.14 355.31 0.18 4,756.54 0.54 2.38EQUI 61 745 TK 012 Gasoline 1,444,674 104 150,246,096 411,633 17,151 3,649.79 1.82 290.03 0.15 905.48 0.45 4,845.30 0.55 2.42EQUI 62 805 TK 013 Gasoline 3,013,668 104 313,421,472 858,689 35,779 5,958.69 2.98 492.59 0.25 1,939.17 0.97 8,390.45 0.96 4.20EQUI 63 806 TK 014 Gasoline 2,972,004 104 309,088,416 846,818 35,284 6,131.74 3.07 485.78 0.24 1,866.60 0.93 8,484.12 0.97 4.24EQUI 64 807 TK 015 Gasoline 3,013,752 104 313,430,208 858,713 35,780 6,008.11 3.00 492.61 0.25 1,866.60 0.93 8,367.32 0.96 4.18EQUI 65 808 TK 016 Gasoline 3,014,424 104 313,500,096 858,904 35,788 6,131.74 3.07 492.72 0.25 1,866.60 0.93 8,491.06 0.97 4.25EQUI 66 809 TK 017 Jet Kerosene 3,297,420 104 342,931,680 939,539 39,147 378.78 0.19 2,525.74 1.26 0.00 2,904.52 0.33 1.45EQUI 67 810 TK 018 Jet Kerosene 3,296,244 104 342,809,376 939,204 39,133 378.78 0.19 2,525.40 1.26 0.00 2,904.18 0.33 1.45EQUI 69 813 TK 019 Gasoline 3,042,060 104 316,374,240 866,779 36,116 19,330.64 9.67 547.37 0.27 1,866.60 0.93 21,744.62 2.48 10.87EQUI 38 814 TK 020 Gasoline 3,041,766 104 316,343,664 866,695 36,112 15,563.67 7.78 524.53 0.26 1,866.60 0.93 17,954.80 2.05 8.98EQUI 70 815 TK 021 Jet Kerosene 3,299,352 104 343,132,608 940,089 39,170 378.78 0.19 2,526.30 1.26 0.00 2,905.08 0.33 1.45EQUI 71 816 TK 022 Jet Kerosene 3,299,856 104 343,185,024 940,233 39,176 378.78 0.19 2,526.45 1.26 0.00 2,905.22 0.33 1.45EQUI 72 817 TK 023 Jet Kerosene 3,299,394 104 343,136,976 940,101 39,171 378.78 0.19 2,526.31 1.26 0.00 2,905.09 0.33 1.45EQUI 73 818 TK 024 Jet Kerosene 3,304,056 104 343,621,824 941,430 39,226 378.78 0.19 2,527.66 1.26 0.00 2,906.44 0.33 1.45EQUI 74 819 TK 025 Jet Kerosene 3,304,098 104 343,626,192 941,442 39,227 378.78 0.19 2,527.67 1.26 0.00 2,906.45 0.33 1.45EQUI 75 820 TK 026 Jet Kerosene 3,219,132 104 334,789,728 917,232 38,218 378.78 0.19 2,503.05 1.25 0.00 2,881.83 0.33 1.44EQUI 40 822 TK 027 Gasoline 3,042,564 104 316,426,656 866,922 36,122 21,244.73 10.62 570.26 0.29 1,866.60 0.93 23,681.59 2.70 11.84EQUI 41 823 TK 028 Gasoline 3,047,436 104 316,933,344 868,311 36,180 15,870.42 7.94 571.17 0.29 1,866.60 0.93 18,308.19 2.09 9.15EQUI 77 824 TK 029 Gasoline 3,042,942 104 316,465,968 867,030 36,126 21,244.73 10.62 570.33 0.29 1,866.60 0.93 23,681.66 2.70 11.84EQUI 78 825 TK 030 Jet Kerosene 3,304,308 104 343,648,032 941,501 39,229 378.78 0.19 2,527.74 1.26 0.00 2,906.51 0.33 1.45EQUI 79 826 TK 031 Jet Kerosene 3,303,846 104 343,599,984 941,370 39,224 378.78 0.19 2,527.60 1.26 0.00 2,906.38 0.33 1.45EQUI 80 827 TK 032 Gasoline 3,299,352 104 343,132,608 940,089 39,170 15,807.67 7.90 618.39 0.31 1,866.60 0.93 18,292.66 2.09 9.15EQUI 81 828 TK 033 Jet Kerosene 3,298,596 104 343,053,984 939,874 39,161 378.78 0.19 2,526.08 1.26 0.00 2,904.86 0.33 1.45EQUI 82 904 TK 034 Denatured Ethanol 195,216 104 20,302,464 55,623 2,318 1,815.70 0.91 11,886.22 5.94 0.00 13,701.92 1.56 6.85

Totals 179,904.93 89.95 47,793.28 23.90 23,216.65 11.61 250,914.86 28.64 125.46

Note: 1. AST standing and working losses (lb/yr) generated from the Tank Emissions Software Program (TankESP) using 2016 data. TankESP summary sheet included for reference. TankESP applies AP-42, Chap 7.1 methodology.

2. AST floating roof landing losses (lb/yr) generated from TankESP and checked against calculations that used equations from AP-42, Chapter 7.1 .

Annual (gal/yr)

Average Daily

(gal/day)

Average Hourly (gal/hr)

Standing Loss 1 Working Loss 1Floating Roof

Landings Loss 2Potential Annual

Turnovers

Potential Throughput

Subject Item ID

Tank No.

Emission Point

Most Volatile Product Stored

Capacity(gal)

VOC Emissions

Total

Magellan Pipeline Company, L.P. - St. Paul Terminal Potential to Emit - Tanks Summary

HAP Fractions of VOC

(lb/yr) (ton/yr)

2,2,4 trimethyl pentane Benzene

Ethyl Benzene Hexane Toluene

Total Xylenes

Total HAP Pollutant

Fraction of VOC

EQUI 49 425 TK 001 1,677.44 0.84 0.0067 0.0075 0.0008 0.0134 0.0109 0.0042 0.0436 2,2,4 Trimethylpentan 0.008EQUI 50 509 TK 002 3,184.14 1.59 0.0127 0.0143 0.0016 0.0255 0.0207 0.0080 0.0828 Benzene 0.009EQUI 51 510 TK 004 3,305.83 1.65 0.0132 0.0149 0.0017 0.0264 0.0215 0.0083 0.0860 Ethyl Benzene 0.001EQUI 52 646 TK 003 3,781.65 1.89 0.0151 0.0170 0.0019 0.0303 0.0246 0.0095 0.0983 Hexane 0.016EQUI 53 649 TK 005 3,628.78 1.81 0.0145 0.0163 0.0018 0.0290 0.0236 0.0091 0.0943 Toluene 0.013EQUI 54 650 TK 006 3,659.80 1.83 0.0146 0.0165 0.0018 0.0293 0.0238 0.0091 0.0952 Total Xylenes 0.005EQUI 55 717 TK 007 4,760.25 2.38 0.0190 0.0214 0.0024 0.0381 0.0309 0.0119 0.1238EQUI 56 718 TK 008 4,759.84 2.38 0.0190 0.0214 0.0024 0.0381 0.0309 0.0119 0.1238EQUI 58 719 TK 009 4,760.05 2.38 0.0190 0.0214 0.0024 0.0381 0.0309 0.0119 0.1238EQUI 59 720 TK 010 4,760.32 2.38 0.0190 0.0214 0.0024 0.0381 0.0309 0.0119 0.1238EQUI 60 743 TK 011 4,756.54 2.38 0.0190 0.0214 0.0024 0.0381 0.0309 0.0119 0.1237EQUI 61 745 TK 012 4,845.30 2.42 0.0194 0.0218 0.0024 0.0388 0.0315 0.0121 0.1260EQUI 62 805 TK 013 8,390.45 4.20 0.0336 0.0378 0.0042 0.0671 0.0545 0.0210 0.2182EQUI 63 806 TK 014 8,484.12 4.24 0.0339 0.0382 0.0042 0.0679 0.0551 0.0212 0.2206EQUI 64 807 TK 015 8,367.32 4.18 0.0335 0.0377 0.0042 0.0669 0.0544 0.0209 0.2176EQUI 65 808 TK 016 8,491.06 4.25 0.0340 0.0382 0.0042 0.0679 0.0552 0.0212 0.2208EQUI 66 809 TK 017 2,904.52 1.45 0.0116 0.0131 0.0015 0.0232 0.0189 0.0073 0.0755EQUI 67 810 TK 018 2,904.18 1.45 0.0116 0.0131 0.0015 0.0232 0.0189 0.0073 0.0755EQUI 69 813 TK 019 21,744.62 10.87 0.0870 0.0979 0.0109 0.1740 0.1413 0.0544 0.5654EQUI 38 814 TK 020 17,954.80 8.98 0.0718 0.0808 0.0090 0.1436 0.1167 0.0449 0.4668EQUI 70 815 TK 021 2,905.08 1.45 0.0116 0.0131 0.0015 0.0232 0.0189 0.0073 0.0755EQUI 71 816 TK 022 2,905.22 1.45 0.0116 0.0131 0.0015 0.0232 0.0189 0.0073 0.0755EQUI 72 817 TK 023 2,905.09 1.45 0.0116 0.0131 0.0015 0.0232 0.0189 0.0073 0.0755EQUI 73 818 TK 024 2,906.44 1.45 0.0116 0.0131 0.0015 0.0233 0.0189 0.0073 0.0756EQUI 74 819 TK 025 2,906.45 1.45 0.0116 0.0131 0.0015 0.0233 0.0189 0.0073 0.0756EQUI 75 820 TK 026 2,881.83 1.44 0.0115 0.0130 0.0014 0.0231 0.0187 0.0072 0.0749EQUI 40 822 TK 027 23,681.59 11.84 0.0947 0.1066 0.0118 0.1895 0.1539 0.0592 0.6157EQUI 41 823 TK 028 18,308.19 9.15 0.0732 0.0824 0.0092 0.1465 0.1190 0.0458 0.4760EQUI 77 824 TK 029 23,681.66 11.84 0.0947 0.1066 0.0118 0.1895 0.1539 0.0592 0.6157EQUI 78 825 TK 030 2,906.51 1.45 0.0116 0.0131 0.0015 0.0233 0.0189 0.0073 0.0756EQUI 79 826 TK 031 2,906.38 1.45 0.0116 0.0131 0.0015 0.0233 0.0189 0.0073 0.0756EQUI 80 827 TK 032 18,292.66 9.15 0.0732 0.0823 0.0091 0.1463 0.1189 0.0457 0.4756EQUI 81 828 TK 033 2,904.86 1.45 0.0116 0.0131 0.0015 0.0232 0.0189 0.0073 0.0755EQUI 82 904 TK 034 13,701.92 6.85 0.0548 0.0617 0.0069 0.1096 0.0891 0.0343 0.3562

Totals 250,914.86 125.46 1.0037 1.1291 0.1255 2.0073 1.6309 0.6273 6.5238

VOC Hazardous Air Pollutants (ton/yr)

Tank No.

Emission PointSI ID

STORAGE TANK EMISSIONS ESTIMATES - Summary Report

Company: Magellan Pipeline Co Location: MINNEAPOLIS-MN

Days Estimated Total

Estimated Period Year Avg. Conditions

This Period TemD (°F) delta T Insolation Wind Speed

Is this a this

Month Estimated Losses VRU

Efficiency Does this include a

Emissions This Month

VRU Efficiency

Emissions This Month ANNUAL 2016

Avg. Conditions This Period 44.71 18.99 1170.00 10.56 | Is this a

this Month This Month

VRU Efficiency

Does this include a


VRU Efficiency


Return to lnput_Service Liquid Temp Avg Landing Cleaning Standing Workinq normal Tank from tank Total Tank Diam. RVP Throughout Bulk Surface TVP Loss this Tank If Floatinq Roof Landinq operations Cleaning Tank cleaninq VOCs ID No. (feet) Tank Tvoe Product (psi) (gallons) (deq F) (deq F) (psia) Event (davs) Standinq Idle Refillinq (%1 Event Cleaninq (%) (lbs) 425 33.00 domed EFRT Gasoline RVP X.XX 13 420,000 not spec'd 46.30 5.3760 No 0 1,675.04 2.40 0.00% No 0 0.00% 1,677.44 444 27.00 FRT(no floating roof) Kerosene/Jet A 13,363,038 not spec'd 46.30 0.0052 No 0 14.82 99.54 0.00% No 0 0.00% 114.35 445 27.00 FRT(no floating roof) Kerosene/Jet A 13,363,038 not spec'd 46.30 0.0052 No 0 14.82 99.54 0.00% No 0 0.00% 114.35 509 48.00 domed EFRT Gasoline RVP X.XX 13 43,723,680 not spec'd 46.30 5.3760 No 0 2,726.51 171.80 0.00% No 0 0.00% 2,898.31 510 48.00 domed EFRT Gasoline RVP X.XX 13 43,570,800 not spec'd 46.30 5.3760 No 0 2,726.51 171.20 0.00% No 0 0.00% 2,897.70 646 60.00 domed EFRT Gasoline RVP X.XX 13 68,298,048 not spec'd 46.30 5.3760 No 0 3,281.14 214.68 0.00% No 0 0.00% 3,495.82 649 60.00 domed EFRT Gasoline RVP X.XX 13 80,292,576 not spec'd 46.30 5.3760 No 0 2,968.27 252.39 0.00% No 0 0.00% 3,220.65 650 60.00 domed EFRT Gasoline RVP X.XX 13 80,327,520 not spec'd 46.30 5.3760 No 0 2,999.17 . 252.50 0.00% No 0 0.00% 3,251.67 717 78.00 domed EFRT Gasoline RVP X.XX 13 117,503,568 not spec'd 46.30 5.3760 No 0 4,120.82 284.12 0.00% No 0 0.00% 4,404.94 718 78.00 domed EFRT Gasoline RVP X.XX 13 117,333,216 not spec'd 46.30 5.3760 No 0 4,120.82 283.71 0.00% No 0 0.00% 4,404.53 719 78.00 domed EFRT Gasoline RVP X.XX 13 117,418,288 not spec'd 46.30 5.3760 No 0 4,120.82 283.91 0.00% No 0 0.00% 4,404.74 720 78.00 domed EFRT Gasoline RVP X.XX 13 117,529,776 not spec'd 46.30 5.3760 No 0 4,120.82 284.18 0.00% No 0 0.00% 4,405.01 743 78.00 domed EFRT Gasoline RVP X.XX 13 115,970,400 not spec'd 46.30 5.3760 No 0 4,120.82 280.41 0.00% No 0 0.00% 4,401.23 745 82.00 domed EFRT Natural Gasoline 14 150,246,096 not spec'd 46.30 5.7374 No 0 3,649.79 290.03 0.00% No 0 0.00% 3,939.82 805 120.00 domed EFRT Gasoline RVP X.XX 13 313,421,472 not spec'd 46.30 5.3760 No 0 5,958.69 492.59 0.00% No 0 0.00% 6,451.28 806 120.00 domed EFRT Gasoline RVP X.XX 13 309,088,416 not spec'd 46.30 5.3760 No 0 6,131.74 485.78 0.00% No 0 0.00% 6,617.52 807 120.00 domed EFRT Gasoline RVP X.XX 13 313,430,208 not spec'd 46.30 5.3760 No 0 6,008.11 492.61 0.00% No 0 0.00% 6,500.72 808 120.00 domed EFRT Gasoline RVP X.XX 13 313,500,096 not spec'd 46.30 5.3760 No 0 6,131.74 492.72 0.00% No 0 0.00% 6,624.46 809 120.00 FRT(no floating roof) Kerosene/Jet A 342,931,680 not spec'd 46.30 0.0052 No 0 378.78 2,525.74 0.00% No 0 0.00% 2,904.52 810 120.00 FRT(no floating roof) Kerosene/Jet A 342,809,376 not spec'd 46.30 0.0052 No 0 378.78 2,525.40 0.00% No 0 0.00% 2,904.18 813 120.00 cone-roof tank w/IFR Gasoline RVP X.XX 13 316,374,240 not spec'd 46.30 5.3760 No 0 19,330.64 547.37 0.00% No 0 0.00% 19,878.02 814 120.00 cone-roof tank w/IFR Gasoline RVP X.XX 13 316,343,664 not spec'd 46.30 5.3760 No 0 15,563.67 524.53 0.00% No 0 0.00% 16,088.20 815 120.00 FRT(no floating roof) Kerosene/Jet A 343,132,608 not spec'd 46.30 0.0052 No 0 378.78 2,526.30 0.00% No 0 0.00% 2,905.08 816 120.00 FRT(no floating roof) Kerosene/Jet A 343,185,024 not spec'd 46.30 0.0052 No 0 378.78 2,526.45 0.00% No 0 0.00% 2,905.22

817 120.00 FRT(no floating roof) Kerosene/Jet A 343,136,976 not spec'd 46.30 0.0052 No 0 378.78 2,526.31 0.00% No 0 0.00% 2,905.09

818 120.00 FRT(no floating roof) Kerosene/Jet A 343,621,824 not spec'd 46.30 0.0052 No 0 378.78 2,527.66 0.00% No 0 0.00% 2,906.44 819 120.00 FRT(no floating roof) Kerosene/Jet A 343,626,192 not spec'd 46.30 0.0052 No 0 378.78 2,527.67 0.00% No 0 0.00% 2,906.45


822 120.00 cone-roof tank w/IFR Gasoline RVP X.XX 13 316,426,656 not spec'd 46.30 5.3760 No 0 21,244.73 570.26 0.00% No 0 0.00% 21,814.99 823 120.00 cone-roof tank w/IFR Gasoline RVP X.XX 13 316,933,344 not spec'd 46.30 5.3760 No 0 15,870.42 571.17 0.00% No 0 0.00% 16,441.59

824 120.00 cone-roof tank w/IFR Gasoline RVP X.XX 13 316,465,968 not spec'd 46.30 5.3760 No 0 21,244.73 570.33 0.00% No 0 0.00% 21,815.06



827 120.00 cone-roof tank w/IFR Gasoline RVP X.XX 13 343,132,608 not spec'd 46.30 5.3760 No 0 15,807.67 618.39 0.00% No 0 0.00% 16,426.06


file: MN-MINNEAPOLIS, TankESP updated fittings 2017 and RVP 13 PTE; sheet: TankSummaries

Magellan Pipeline Company, L.P. - St. Paul Terminal Potential to Emit - Additives Tanks Details

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

210-444 Jet Kerosene 128,491 104 13,363,038 36,611 1,525 14.82 0.007 99.54 0.050 114.35 0.057 0.013210-445 Jet Kerosene 128,491 104 13,363,038 36,611 1,525 14.82 0.007 99.54 0.050 114.35 0.057 0.013210-130 Fuel Additives 6,000 12 72,000.00 197.26 8.22 88.50 0.044 133.59 0.067 222.09 0.111 0.025210-080 Fuel Additives 1,981 12 23,772.00 65.13 2.71 30.23 0.015 44.11 0.022 74.33 0.037 0.008210-160 Fuel Additives 2,005 12 24,060.00 65.92 2.75 30.23 0.015 44.64 0.022 74.87 0.037 0.009210-132 Fuel Additives 6,000 12 72,000.00 197.26 8.22 88.50 0.044 133.59 0.067 222.09 0.111 0.025210-133 Fuel Additives 1,026 12 12,312.00 33.73 1.41 16.32 0.008 22.84 0.011 39.17 0.020 0.004210-010 Fuel Additives 1,030 12 12,360.00 33.86 1.41 16.32 0.008 22.93 0.011 39.26 0.020 0.004210-138 Fuel Additives 6,000 12 72,000.00 197.26 8.22 88.50 0.044 133.59 0.067 222.09 0.111 0.025210-134 Fuel Additives 1,002 12 12,024.00 32.94 1.37 15.44 0.008 22.31 0.011 37.75 0.019 0.004210-021 Fuel Additives 4,000 12 48,000.00 131.51 5.48 60.38 0.030 89.06 0.045 149.44 0.075 0.017210-135 Fuel Additives 1,003 12 12,036.00 32.98 1.37 15.44 0.008 22.33 0.011 37.77 0.019 0.004210-040 Fuel Additives 1,003 12 12,036.00 32.98 1.37 15.44 0.008 22.33 0.011 37.77 0.019 0.004383-060 Fuel Additives 11,980 12 143,760.00 393.86 16.41 172.48 0.086 266.74 0.133 439.21 0.220 0.050383-080 Fuel Additives 8,000 12 96,000.00 263.01 10.96 114.54 0.057 178.12 0.089 292.66 0.146 0.033383-110 Fuel Additives 4,136 12 49,632.00 135.98 5.67 60.10 0.030 92.09 0.046 152.19 0.076 0.017383-061 Fuel Additives 5,987 12 71,844.00 196.83 8.20 86.67 0.043 133.30 0.067 219.97 0.110 0.025383-065 Fuel Additives 2,005 12 24,060.00 65.92 2.75 29.22 0.015 44.64 0.022 73.86 0.037 0.008383-062 Fuel Additives 1,026 12 12,312.00 33.73 1.41 15.90 0.008 22.84 0.011 38.75 0.019 0.004383-064 Fuel Additives 519 12 6,228.00 17.06 0.71 8.31 0.004 11.56 0.006 19.87 0.010 0.002383-133 Fuel Additives 750 12 9,000.00 24.66 1.03 11.69 0.006 16.70 0.008 28.39 0.014 0.003383-135 Fuel Additives 550 12 6,600.00 18.08 0.75 8.92 0.004 12.25 0.006 21.17 0.011 0.002383-138 Fuel Additives 10,000 12 120,000.00 328.77 13.70 145.53 0.073 222.65 0.111 368.18 0.184 0.042383-160 Fuel Additives 3,000 12 36,000.00 98.63 4.11 44.46 0.022 66.80 0.033 111.26 0.056 0.013

Totals 1,192.752 0.596 1,958.10 0.979 3,150.85 1.575 0.360

Note:

Per Minn. R. 7007.1300, subp. 3(I), the following tanks qualify as insignificant activites. 1

1. Minn. R. 7007.1300, subp. 3(I)(2): Individual emission units at a stationary source qualify as insignificant activities if each of which have a potential to emit VOCs (including hazardous air pollutant-containing VOCs) in amounts less than 2,000 pounds per year.

2. AST standing and working losses (lb/yr) generated from TankESP (applying AP-42 Chapter 7.1 methodology). TankESP summary sheet included for reference.

Tank No.Most Volatile Product Stored

Potential

Annual Turnove

rs

VOC Emissions

Capacity

(gal)Annual(gal/yr)

Average Daily

(gal/day)

Average Hourly(gal/hr)

Standing Loss 2Working/

Re-filling Loss 2 Total

Potential Throughput

Magellan Pipeline Company, L.P. - St. Paul Terminal Potential to Emit - Additives Tanks Summary

HAP Fractions of VOC

(lb/yr) (ton/yr)

2,2,4 trimethyl pentane Benzene

Ethyl Benzene Hexane Toluene

Total Xylenes

Total HAP Pollutant

Fraction of VOC

210-444 114.35 0.06 0.000 0.001 0.0001 0.0009 0.0007 0.0003 0.003 2,2,4 Trimethylpentan 0.008210-445 114.35 0.06 0.000 0.001 0.0001 0.0009 0.0007 0.0003 0.003 Benzene 0.009210-130 222.09 0.11 0.0009 0.001 0.0001 0.0018 0.0014 0.0006 0.006 Ethyl Benzene 0.001210-080 74.33 0.04 0.0003 0.000 0.0000 0.0006 0.0005 0.0002 0.002 Hexane 0.016210-160 74.87 0.04 0.0003 0.000 0.0000 0.0006 0.0005 0.0002 0.002 Toluene 0.013210-132 222.09 0.11 0.0009 0.001 0.0001 0.0018 0.0014 0.0006 0.006 Total Xylenes 0.005210-133 39.17 0.02 0.0002 0.000 0.0000 0.0003 0.0003 0.0001 0.001210-010 39.26 0.02 0.0002 0.000 0.0000 0.0003 0.0003 0.0001 0.001210-138 222.09 0.11 0.0009 0.001 0.0001 0.0018 0.0014 0.0006 0.006210-134 37.75 0.02 0.0002 0.000 0.0000 0.0003 0.0002 0.0001 0.001210-021 149.44 0.07 0.0006 0.001 0.0001 0.0012 0.0010 0.0004 0.004210-135 37.77 0.02 0.0002 0.000 0.0000 0.0003 0.0002 0.0001 0.001210-040 37.77 0.02 0.0002 0.000 0.0000 0.0003 0.0002 0.0001 0.001383-060 439.21 0.22 0.0018 0.002 0.0002 0.0035 0.0029 0.0011 0.011383-080 292.66 0.15 0.0012 0.001 0.0001 0.0023 0.0019 0.0007 0.008383-110 152.19 0.08 0.0006 0.001 0.0001 0.0012 0.0010 0.0004 0.004383-061 219.97 0.11 0.0009 0.001 0.0001 0.0018 0.0014 0.0005 0.006383-065 73.86 0.04 0.0003 0.000 0.0000 0.0006 0.0005 0.0002 0.002383-062 38.75 0.02 0.0002 0.000 0.0000 0.0003 0.0003 0.0001 0.001383-064 19.87 0.01 0.0001 0.000 0.0000 0.0002 0.0001 0.0000 0.001383-133 28.39 0.01 0.0001 0.000 0.0000 0.0002 0.0002 0.0001 0.001383-135 21.17 0.01 0.0001 0.000 0.0000 0.0002 0.0001 0.0001 0.001383-138 368.18 0.18 0.0015 0.002 0.0002 0.0029 0.0024 0.0009 0.010383-160 111.26 0.06 0.0004 0.001 0.0001 0.0009 0.0007 0.0003 0.003

Totals 3,150.85 1.58 0.0126 0.0142 0.0016 0.0252 0.0205 0.0079 0.082

Note:

Tank No.

VOC Hazardous Air Pollutants (ton/yr)

Per Minn. R. 7007.1300, subp. 3(I), the following tanks qualify as insignificant activites. 1


STORAGE TANK EMISSIONS ESTIMATES - Summary ReportCompany: Magellan Pipeline Co. Location: MINNEAPOLIS-MN Total

Days Days Estimated EstimatedPeriod Year Avg. Conditions Temp (oF) delta T Insolation Wind Speed this this VRU Does this Emissions VRU Emissions

ANNUAL 2012 This Period 44.71 18.99 1170.00 10.56 Is this a Month Month Efficiency include a This Month Efficiency This Month

Avg Landing in this Cleaning Standing Working normal Tank from tank TotalTank Diam. RVP Throughput Bulk Surface TVP Loss Service this Tank operations Cleaning Tank cleaning VOCsID No. (feet) Tank Type Product (psi) (gallons) (deg F) (deg F) (psia) Event (days) (days) Standing Idle Refilling (%) Event Cleaning (%) (lbs)

Return to Input_Service Liquid Temp

This MonthEstimated Losses

If Floating Roof Landing

file: MN-MINNEAPOLIS_TankESP.xlsm; sheet: TankSummaries

ID No. (feet) Tank Type Product (psi) (gallons) (deg F) (deg F) (psia) Event (days) (days) Standing Idle Refilling (%) Event Cleaning (%) (lbs)133 6.42 horizontal tank Jet naphtha (JP-4) 9,000 not spec'd 46.3 0.94 No 365 0 11.69 16.70 0.00% No 0 0.00% 28.39135 5.60 horizontal tank Jet naphtha (JP-4) 6,600 not spec'd 46.3 0.94 No 365 0 8.92 12.25 0.00% No 0 0.00% 21.16138 16.58 horizontal tank Jet naphtha (JP-4) 120,000 not spec'd 46.3 0.94 No 365 0 145.53 222.65 0.00% No 0 0.00% 368.18160 10.40 horizontal tank Jet naphtha (JP-4) 36,000 not spec'd 46.3 0.94 No 365 0 44.46 66.80 0.00% No 0 0.00% 111.26

file: MN-MINNEAPOLIS_TankESP.xlsm; sheet: TankSummaries

Magellan Pipeline Company, L.P. - St. Paul Terminal Potential to Emit - Railcar Loading Rack


Fuel Oil

Saturation Factor, S 3 0.60

Avg. True Vapor Pressure, P (psia) 0.0039Vapor Molecular Weight, M 4 (lb/lb-mole 130Loading Temperature, T (oF) 44.7Loading Loss Factor, LL (lb/1000-gal) 0.008

Throughput and Loading InformationPotential Rack Throughput (1000-gal/yr) 126,000

% of Loading that is Balanced 0%

% of Loading that is Normal (not balance 100%Vapor Control Type NoneEnforceable limit for gasoline loading None

lb/yr 947

lb/hr 0.11ton/yr 0.47

2,2,4 Trimethylpentane 0.008 0.004Benzene 0.009 0.004Ethyl Benzene 0.001 0.000Hexane 0.016 0.008Toluene 0.013 0.006Total Xylenes 0.005 0.002

0.025

Note:

2. Loading Loss Factor equation from AP-42 Chapter 5.2: Transportation of Petroleum Liquids, pg 5.2-4.

3. Source: EPA AP-42 Table 5.2-1

4. Source: AP-42 Table 7.1-2. Properties of Jet kerosene

1. Minn. R. 7007.1300, subp. 4: An emission unit at a stationary source qualifies as an insignificant activity in an initial part 70 permit if it has potential emissions of less than 2.28 pounds per hour or actual emissions of less than 1 ton per year for VOCs, and combined HAP actual emissions of less than 1 ton per year.

Per Minn. R. 7007.1300, subp. 4, on-site railcar loading qualifies as an insignificant activity. 1

Potential Uncontrolled VOC Emissions = LL*Q

PollutantFraction of

VOCHAP Emissions

(ton/yr)

Total HAP

Magellan Pipeline Company, L.P. - St. Paul Terminal Potential to Emit - Ethanol UnloadingPer Minn. R. 7007.1300, subp. 4, on-site ethanol unloading qualifies as an insignificant activity. 1


0.60

0.9421

46.38

46.30.65

Annual Ethanol Throughput, QEthanol Units

16.00 inches1.33 feet8.00 feet

11.17 ft3

55.71 gallon8 1000-gallon

840,960 1000-gallon/year84,096 1000-gallon/year10,512 EtOH trucks/year

586 1000-gallon/year

lb/yr 378lb/hr 0.04

ton/yr 0.19

HAP Fractions of VOCPollutant Gas Fraction of VOC Ethanol 8 HAP (ton/yr)

2,2,4 Trimethylpentane 0.008 0.00016 3.024E-05Benzene 0.009 0.00018 3.402E-05Ethyl Benzene 0.001 0.00002 3.781E-06Hexane 0.016 0.00032 6.049E-05Toluene 0.013 0.00026 4.915E-05Total Xylenes 0.005 0.00010 1.890E-05

0.0002

Notes:

2. Loading Loss Factor equation from AP-42 Chapter 5.2: Transportation & Marketing of Petroleum Liquids, pg 5.2-4.

3. Source: EPA AP-42 Table 5.2-1.


Potential Uncontrolled VOC Emissions = LL*Q

Annual Ethanol unloading limit (assume 10% of gasoline limit)Annual maximum number of Ethanol unloading trucks per yearQ

8. Denatured ethanol includes up to 2% gasoline as denaturant; therefore, potential HAP fractions are 2% gasoline HAP fractions.

7. Volume loaded is calculated as the unloading pipe volume multiplied by 2/3, due to the assumption that only 2/3 of the pipe is filled with emissions for loading loss due to engineering design.

6. Loading temperature is the liquid surface temperature. Most of the PTE used bulk temperature, but since the ethanol is from a tank truck, it is assumed it's warmer than product from a pipeline or AST.

5. Molecular weight is for denatured ehtanol that includes up to 2% gasoline as denaturant.

4. Denatured ethanol assumed to have be RVP 3.7, which was used to extrapolate the TVP at the designated temp.

Vapor Molecular Weight, M (lb/lb-mole) 5Avg. True Vapor Pressure, P (psia) 4Saturation Factor, S 3

Total HAP

Unloading pipe diameter

Unloading pipe lengthUnloading pipe volumeevent 7

Maximum unloading tanker volumeAnnual Gasoline loading limit (sum of 2 LR)

Loading Loss Factor, LL (lb/1000-gal)Loading Temperature, T (oF) 6

Magellan Pipeline Company, L.P. - St. Paul Terminal Potential to Emit - Butane Unloading, Sampling, and System Maintenance

Butane Unloading Emissions per Station

V = Hose volume (ft3) / D = Density of Butane (lb/gal) / EA = Events per Year

Pipe Diameter

Unloading Pipe Length

Butane Density

PTE

(in) (ft) (ft3) (gal) (lb/gal) (ton/yr)Butane Truck Unloading 2 1.50 0.03 0.245 5.06 500 0.31

Butane Sample Tee Purging Emissions per Station

V = Tee volume (ft3)

Butane Density PTE

(ft3) (gal) (lb/gal) (ton/yr)Butane Sample Tee Purging 0.0177 0.132 5.06 0.5 4380 1.46

Butane Routine Maintenance Emissions per Station

Pipe Diameter

Pipe LengthButane Density

PTE

(in) (ft) (ft3) (gal) (lb/gal) (ton/yr)Butane System Routine Maintenan 2 20.00 0.44 3.264 5.06 6 0.05

Summary of Potential VOC Emissions for Three (3) Butane Unloading Stations(lb/hr)

Truck Unloading

Sample Tee Purging

Maintenance Total Total

Butane Station #1 0.31 0.00 0.05 0.36 0.082Butane Station #2 0.31 0.00 0.05 0.36 0.082Butane Station #3 0.31 0.00 0.05 0.36 0.082

Totals 1.08 0.246

Note:

2. Unloading volume lost per event assumes all liquid between the shut-off valve and coupler evaporates. Butane vaporizes almost instantaneously.

Pipe Volume 2Service

Events per Year


Emissions Source

Potential VOC Emissions (ton/yr)

Emission Source

Per Minn. R. 7007.1300, subp. 4, on-site butane unloading, routine maintenance, and sample purging qualify as an insignificant a

Emission Source

Unloading Pipe Volume 2Unloading Events per

Year

Potential emissions from sample-tee purging are estimated using the equation: Maximum Annual Emissions = V*D*E A , where

Potential emissions from butane unloading are estimated using the equation: Maximum Annual Emissions = V*D*E A , where

Emission Source

Purged Sample Tee Tubing Volume Purges per

hourPurges per

year

Potential emissions from system maintenace are estimated using the equation: Maximum Hourly Emissions = V*D*E A , where

Magellan Pipeline Company, L.P. - St. Paul Terminal Potential to Emit - Biodiesel Unloading

Bio-diesel Unloading Emissions

V = Volume Emitted per Disconnect (gal/event) / D = Density of Biodiesel Fuel (lb/gal) / E = Events per Year

Emission Source

Unloading Volume

(gal/event) 2Density(lb/gal)

Events per year

Potential to Emit(lb/yr)

Potential to Emit(ton/yr)

HAP PTE (ton/yr)

Biodiesel Truck Unloading 0.001302083 7.00 200 1.82 0.0009 4.74E-05

Note:

Per Minn. R. 7007.1300, subp. 3(I), biodiesel unloading qualifies as an insignificant activity. 1

Potential emissions from bio-diesel unloading are estimated using the equation: Maximum Hourly Emissions = V*D*E , where


2. Unloading volume lost per event assumes all liquid between the shut-off valve and coupler evaporates. Most of biodiesel gets soaked up by sorbent pads, but for worst case scenario, it is assumed it all vaporizes.

Magellan Pipeline Company, L.P. - St. Paul Terminal Potential to Emit - Equipment Fugitives

Item

Estimated No. at

Facility

VOC Emission

Factor 1

(lb/hr/component)

VOC Emissions

(lb/hr)

VOC Emissions

(ton/yr)Pump Seals (Liquid) 204 1.19E-03 0.243 1.06Flange Sets 7,594 1.80E-05 0.137 0.60Loading Rack Valves (Vapor) 24 2.90E-05 0.001 0.00Loading Rack Valves (Liquid) 364 9.50E-05 0.035 0.15Other Valves (Liquid) 1,914 2.90E-04 0.555 2.43Open-ended lines (gas) 0 6.70E-03 0 0.00

Total 0.970 4.25

Note:

Hazardous Air PollutantFraction of

VOC

Potential HAP Emissions (ton/yr)

2,2,4 Trimethylpentane 0.008 0.034Benzene 0.009 0.038Ethyl Benzene 0.001 0.004Hexane 0.016 0.068Toluene 0.013 0.055Total Xylenes 0.005 0.021

Total HAP 0.221

1. All emission factors taken from Table 2-3 of EPA Bulletin 453/R-95-017, Protocol for Equipment Leak Emission Estimates, November 1995.

Magellan Pipeline Company, L.P. - St. Paul Terminal

Potential to Emit - Facility Totals (ton/yr)

Insignificant Activity

Tanks(ton/yr)

Railcar Loading

Rack(ton/yr)

Ethanol Unloading

(ton/yr)

Butane Unloading

(ton/yr)

Biodiesel Unloading

(ton/yr)

Equipment Fugitives(ton/yr)

Total Emissions

(ton/yr)VOC 86.53 86.53 0.01 125.46 1.58 0.47 0.19 1.08 0.00 4.25 306Total Particulates NA NA 0.01 NA NA NA NA NA NA NA 0.012PM-10 NA NA 0.01 NA NA NA NA NA NA NA 0.009PM-2.5 NA NA 0.00 NA NA NA NA NA NA NA 0.003SO2 NA NA 0.00 NA NA NA NA NA NA NA 0.001CO 35.09 35.09 0.13 NA NA NA NA NA NA NA 70.3NOx 14.04 14.04 0.16 NA NA NA NA NA NA NA 28.2CO2e NA NA 190 NA NA NA NA NA NA NA 1902,2,4 Trimethylpentan 0.69 0.69 NA 1.00 0.013 0.004 0.000 NA 0.000 0.034 2.4Benzene 0.78 0.78 0.00 1.13 0.014 0.004 0.000 NA 0.000 0.038 2.7Ethyl Benzene 0.09 0.09 NA 0.13 0.002 0.000 0.000 NA 0.000 0.004 0.30Hexane 1.38 1.38 0.00 2.01 0.025 0.008 0.000 NA 0.000 0.068 4.88Toluene 1.12 1.12 0.00 1.63 0.020 0.006 0.000 NA 0.000 0.055 4.0Total Xylenes 0.43 0.43 NA 0.63 0.008 0.002 0.000 NA 0.000 0.021 1.5Total HAP 4.50 4.50 0.02 6.52 0.08 0.02 0.00 0.00 0.00 0.22 15.9

Potential to Emit - Facility Totals (lb/hr)

Insignificant Activity

Tanks(lb/hr)

Railcar Loading

Rack(lb/hr)

Ethanol Unloading

(lb/hr)

Butane Unloading

(lb/hr)

Bio-diesel Unloading

(lb/hr)

Equipment Fugitives

(lb/hr)

VOC 19.76 19.76 0.00 28.64 0.36 0.11 0.04 0.25 0.00 0.97 69.88CO 8.01 8.01 0.03 NA NA NA NA NA NA NA 16.05NOx 3.20 3.20 0.04 NA NA NA NA NA NA NA 6.45Total HAP 1.03 1.03 0.00 1.49 0.02 0.01 0.00 0.00 0.00 0.05 3.62

Total Emissions

(lb/hr)

Pollutant

MPL Loading

Rack(ton/yr)

FHR Loading

Rack(ton/yr)

Storage Tanks

(ton/yr)

Insignificant emissions sources

Pollutant

MPL Loading

Rack(lb/hr)

FHR Loading

Rack(lb/hr)

Storage Tanks(lb/hr)

Insignificant emissions sources

VCUs pilot flame

(ton/yr)

VCUs pilot flame

(ton/yr)

ATTACHMENT 2:

Subject Item Inventory and Facility Requirements

Agency Interest Name Subject Item ID SI Designation and Description

Magellan Pipeline CoLP - Saint PaulTerminal

ACTV3NullAll IA's

AISI1869NullNull

COMG3NullUnits Subject to NESHAP BBBBBB

EQUI19EU001Tank Truck Bottom Load - MPLw/Vapor Combustor Control

EQUI20EU002Tank Truck Bottom Load - Flint HillsResources (FHR) w/Vapor Combus..

EQUI38TK020Gasoline / 3,041,766 gallons / Tank814



EQUI49TK001Gasoline / 236,628 gallons / Tank425

EQUI50TK002Ethanol / 420,420 gallons / Tank509


EQUI52 TK003Ethanol / 656,712 gallons / Tank646

List of SIs

Agency Interest: Magellan Pipeline Co LP - Saint PaulTerminalAgency Interest ID: 1869Activity: IND20100001 (Part 70 Reissuance)

Details for:SI Category: NoneSI Type: All

Agency Interest Name Subject Item ID SI Designation and DescriptionMagellan Pipeline CoLP - Saint PaulTerminal

EQUI51

TK004Gasoline / 418,950 gallons / Tank510




EQUI55TK007Fuel Oil #2 / 1,129,842 gallons /Tank 717








EQUI64 TK015Gasoline / 3,013,752 gallons / Tank807

List of SIs




EQUI63

TK014Gasoline / 2,972,004 gallons / Tank806





EQUI69TK019Ethanol / 3,042,060 gallons / Tank813





EQUI74TK025Jet kerosene / 3,304,098 gallons /Tank 819


EQUI77 TK029Gasoline / 3,042,942 gallons / Tank824

List of SIs




EQUI75

TK026Fuel Oil #2 / 3,219,132 gallons /Tank 820


EQUI78TK030Jet kerosene / 3,304,308 gallons /Tank 825





FUGI1FS001Valves, Pump Seals, Flanges &Connectors.

STRU1SV001Stack/Vent


STRU4NullTerminal Office

STRU5NullShop/Lab

STRU6 NullRail & Ethanol Controls

List of SIs




STRU5NullShop/Lab

STRU6NullRail & Ethanol Controls

STRU7NullWarehouse

STRU8NullRack Canopy

STRU9NullRail Canopy

STRU10NullStation

STRU11NullChange Room

STRU12NullPump Shelter

STRU13NullMPL Additive

STRU14NullFHR Additive

STRU15NullPreCard

STRU16NullStorage (Blue)

STRU17 NullStorage (Tan)

List of SIs





STRU17NullStorage (Tan)

STRU18NullTech Shop - Terminal

STRU19NullMPL Driver Building

STRU20NullFHR Driver Building

STRU21NullBiodiesel Offload

TFAC112300070Magellan Pipeline Co LP - St Paul

TREA6CE001Vapor Combustion Unit (VCU)


List of SIs



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


IND20100001 Activity Insignificant Air Emissions Activity ACTV3 NullAll IA's

Active /Existing

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

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

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

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

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

Minn. R. 7007.1300, subp. 4

Insignificant air emissions activity

Agency Interest: Magellan Pipeline Co LP - Saint Paul TerminalAgency Interest ID: 1869Activity: IND20100001 (Part 70 Reissuance)

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

Agency Interest Name Subject Item ID SI Designation and Description Group Member ID (padded)


COMG3 NullUnits Subject to NESHAP BBBBBB

EQUI19

EQUI20

EQUI38

EQUI40

EQUI41

EQUI49

EQUI50

EQUI51

EQUI52

EQUI53

EQUI54

EQUI55

EQUI56

EQUI58

EQUI59

EQUI60

Component Group (Members)

Agency Interest: Magellan Pipeline Co LP - Saint Paul TerminalAgency Interest ID: 1869Activity: None (Part 70 Reissuance)

Details for:SI Category: Component GroupSI Type: Air Component Group

Agency Interest Name Subject Item ID SI Designation and Description Group Member ID (padded)Magellan Pipeline CoLP - Saint PaulTerminal

COMG3 NullUnits Subject to NESHAP BBBBBB

EQUI59

EQUI60

EQUI61

EQUI62

EQUI63

EQUI64

EQUI65

EQUI69

EQUI77

EQUI80

TREA6

TREA7

Component Group (Members)

Agency Interest: Magellan Pipeline Co LP - Saint Paul TerminalAgency Interest ID: 1869Activity: None (Part 70 Reissuance)

Details for:SI Category: Component GroupSI Type: Air Component Group

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 Aboveground StorageTank

EQUI38 TK020 Gasoline / 3,041,766gallons / Tank 814

2,2,4-trimethylpentane

Benzene

Ethylbenzene

Hexane

Toluene

Volatile Organic Compoun..

Xylenes, Total



Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total



Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total

EQUI49 TK001 Gasoline / 236,628 gallons/ Tank 425


Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total

EQUI50 TK002 Ethanol / 420,420 gallons/ Tank 509


Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total



Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total



Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total



Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total



Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total

EQUI55 TK007 Fuel Oil #2 / 1,129,842gallons / Tank 717


Benzene

0.04498.9770.11670.14360.0090.08080.0718

0.04498.9770.11670.14360.0090.08080.0718

0.01022.05

0.02660.03280.0020.01840.0164

0.059211.8410.15390.18950.01180.10660.0947

0.059211.8410.15390.18950.01180.10660.0947

0.01352.7030.03510.04330.00270.02430.0216

0.04589.1540.1190.14650.00920.08240.0732

0.04589.1540.1190.14650.00920.08240.0732

0.01042.09

0.02720.03340.00210.01880.0167

0.00420.8390.01090.01340.00080.00750.0067

0.00420.8390.01090.01340.00080.00750.0067

0.0010.1910.00250.00310.00020.00170.0015

0.0081.5920.02070.02550.00160.01430.0127

0.0081.5920.02070.02550.00160.01430.0127

0.00180.3630.00470.00580.00040.00330.0029

0.00831.6530.02150.02640.00170.01490.0132

0.00831.6530.02150.02640.00170.01490.0132

0.00190.3770.00490.0060.00040.00340.003

0.00951.8910.02460.03030.00190.0170.0151

0.00951.8910.02460.03030.00190.0170.0151

0.00220.4320.00560.00690.00040.00390.0035

0.00911.8140.02360.0290.00180.01630.0145

0.00911.8140.02360.0290.00180.01630.0145

0.00210.4140.00540.00660.00040.00370.0033

0.00911.83

0.02380.02930.00180.01650.0146

0.00911.83

0.02380.02930.00180.01650.0146

0.00210.4180.00540.00670.00040.00380.0033

0.0190.0190.0043

PTE by subject item

Agency Interest: NoneAgency Interest ID: 1869Activity: None (Part 70 Reissuance)

Details for:SI Category: AllSI Type: All




Potential (lbs/hr)


(tons/yr)

Potential Limited

(tons/yr)

Actual Emissions

(tons/yr)




Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total



Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total



Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total



Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total



Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total



Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total



Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total



Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total



Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total



Benzene

Ethylbenzene

0.01192.38

0.03090.03810.00240.0214

0.01192.38

0.03090.03810.00240.0214

0.00270.5430.00710.00870.00050.0049

0.01192.38

0.03090.03810.00240.02140.019

0.01192.38

0.03090.03810.00240.02140.019

0.00270.5430.00710.00870.00050.00490.0043

0.01192.38

0.03090.03810.00240.02140.019

0.01192.38

0.03090.03810.00240.02140.019

0.00270.5430.00710.00870.00050.00490.0043

0.01192.38

0.03090.03810.00240.02140.019

0.01192.38

0.03090.03810.00240.02140.019

0.00270.5430.00710.00870.00050.00490.0043

0.01192.3780.03090.03810.00240.02140.019

0.01192.3780.03090.03810.00240.02140.019

0.00270.5430.00710.00870.00050.00490.0043

0.01212.4230.03150.03880.00240.02180.0194

0.01212.4230.03150.03880.00240.02180.0194

0.00280.5530.00720.00880.00060.0050.0044

0.0214.1950.05450.06710.00420.03780.0336

0.0214.1950.05450.06710.00420.03780.0336

0.00480.9580.01250.01530.0010.00860.0077

0.02124.2420.05510.06790.00420.03820.0339

0.02124.2420.05510.06790.00420.03820.0339

0.00480.9690.01260.01550.0010.00870.0077

0.02094.1840.05440.06690.00420.03770.0335

0.02094.1840.05440.06690.00420.03770.0335

0.00480.9550.01240.01530.0010.00860.0076

0.03820.034

0.03820.034

0.00870.0078

PTE by subject item






Potential (lbs/hr)


(tons/yr)

Potential Limited

(tons/yr)

Actual Emissions

(tons/yr)



Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total



Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total



Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total

EQUI69 TK019 Ethanol / 3,042,060gallons / Tank 813


Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total



Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total



Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total



Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total



Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total

EQUI74 TK025 Jet kerosene / 3,304,098gallons / Tank 819


Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total



Benzene

Ethylbenzene

Hexane

0.02124.2460.05520.06790.0042

0.02124.2460.05520.06790.0042

0.00480.9690.01260.01550.001

0.00731.4520.01890.02320.00150.01310.0116

0.00731.4520.01890.02320.00150.01310.0116

0.00170.3320.00430.00530.00030.0030.0027

0.00731.4520.01890.02320.00150.01310.0116

0.00731.4520.01890.02320.00150.01310.0116

0.00170.3320.00430.00530.00030.0030.0027

0.054410.8720.14130.1740.01090.09790.087

0.054410.8720.14130.1740.01090.09790.087

0.01242.4820.03230.03970.00250.02230.0199

0.00731.4530.01890.02320.00150.01310.0116

0.00731.4530.01890.02320.00150.01310.0116

0.00170.3320.00430.00530.00030.0030.0027

0.00731.4530.01890.02320.00150.01310.0116

0.00731.4530.01890.02320.00150.01310.0116

0.00170.3320.00430.00530.00030.0030.0027

0.00731.4530.01890.02320.00150.01310.0116

0.00731.4530.01890.02320.00150.01310.0116

0.00170.3320.00430.00530.00030.0030.0027

0.00731.4530.01890.02330.00150.01310.0116

0.00731.4530.01890.02330.00150.01310.0116

0.00170.3320.00430.00530.00030.0030.0027

0.00731.4530.01890.02330.00150.01310.0116

0.00731.4530.01890.02330.00150.01310.0116

0.00170.3320.00430.00530.00030.0030.0027

0.00140.0130.0115

0.00140.0130.0115

0.00030.0030.0026

PTE by subject item






Potential (lbs/hr)


(tons/yr)

Potential Limited

(tons/yr)

Actual Emissions

(tons/yr)



Ethylbenzene

Hexane

Toluene


Xylenes, Total



Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total

EQUI78 TK030 Jet kerosene / 3,304,308gallons / Tank 825


Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total



Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total



Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total



Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total



Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total

Loading-UnloadingEquipment

EQUI19 EU001 Tank Truck Bottom Load -MPL w/Vapor CombustorControl


Benzene

Carbon Monoxide

Ethylbenzene

Hexane

Nitrogen Oxides

Toluene


Xylenes, Total

EQUI20 EU002 Tank Truck Bottom Load -Flint Hills Resources (FHR)w/Vapor CombustorControl


Benzene

Carbon Monoxide

Ethylbenzene

Hexane

Nitrogen Oxides

Toluene


Xylenes, Total


0.00721.4410.01870.0231

0.00721.4410.01870.0231

0.00160.3290.00430.0053

0.059211.8410.15390.18950.01180.10660.0947

0.059211.8410.15390.18950.01180.10660.0947

0.01352.7030.03510.04330.00270.02430.0216

0.00731.4530.01890.02330.00150.01310.0116

0.00731.4530.01890.02330.00150.01310.0116

0.00170.3320.00430.00530.00030.0030.0027

0.00731.4530.01890.02330.00150.01310.0116

0.00731.4530.01890.02330.00150.01310.0116

0.00170.3320.00430.00530.00030.0030.0027

0.04579.1460.11890.14630.00910.08230.0732

0.04579.1460.11890.14630.00910.08230.0732

0.01042.0880.02710.03340.00210.01880.0167

0.00731.4520.01890.02320.00150.01310.0116

0.00731.4520.01890.02320.00150.01310.0116

0.00170.3320.00430.00530.00030.0030.0027

0.03436.8510.08910.10960.00690.06170.0548

0.03436.8510.08910.10960.00690.06170.0548

0.00781.5640.02030.0250.00160.01410.0125

0.4326486.52731.1248614.036311.384440.0865335.09070.778750.6922

8.405031,681.00621.8530714.0363126.896091.6810135.090715.1290513.44804

0.0987819.75510.256823.20640.316080.019768.0160.17780.158

0.4326486.52731.1248614.03631.384440.0865335.09070.778750.69222

8.405031,681.00621.8530714.036326.896091.6810135.090715.1290513.44804

0.0987819.75510.256823.206

0.316080.019768.0160.17780.15804

PTE by subject item






Potential (lbs/hr)


(tons/yr)

Potential Limited

(tons/yr)

Actual Emissions

(tons/yr)

EquipmentLoading-UnloadingEquipment EQUI20 EU002

Tank Truck Bottom Load -Flint Hills Resources (FHR)w/Vapor CombustorControl Xylenes, Total

Fugitive Equipment Leaks FUGI1 FS001 Valves, Pump Seals,Flanges & Connectors.


Benzene

Ethylbenzene

Hexane

Toluene


Xylenes, Total

Treatment 099-Other TREA6 CE001 Vapor Combustion Unit(VCU)

Benzene

Carbon Dioxide

Carbon Dioxide Equivalent

Carbon Monoxide

HAPs - Total

Hexane

Methane

Nitrogen Oxides

Nitrous Oxide

Particulate Matter

PM < 2.5 micron

PM < 10 micron

Sulfur Dioxide

Toluene


TREA7 CE002 Vapor Combustion Unit(VCU)

Benzene

Carbon Dioxide

Carbon Dioxide Equivalent

Carbon Monoxide

HAPs - Total

Hexane

Methane

Nitrogen Oxides

Nitrous Oxide

Particulate Matter

PM < 2.5 micron

PM < 10 micron

Sulfur Dioxide

Toluene


0.021244.247670.055220.067960.004250.038230.03398

0.021244.247670.055220.067960.004250.038230.03398

0.004850.969790.012610.015520.000970.008730.00776

0.00432.68e-060.00050.00450.00150.006

0.0017340.07880.001810.0014190.008890.066295.1794.61

1.65e-06

0.00432.68e-060.00050.00450.00150.006

0.0017340.07880.001810.0014190.008890.066295.1794.61

1.65e-06

0.0016.12e-070.00010.0010.00030.0014

0.0003960.018

0.000410.0003240.002030.015121.72821.6

3.78e-07

0.00432.68e-060.00050.00450.00150.006

0.0017340.07880.001810.001420.008890.066295.1794.61

1.65e-06

0.00432.68e-060.00050.00450.00150.006

0.0017340.07880.001810.001420.008890.066295.1794.61

1.65e-06

0.0016.12e-070.00010.0010.00030.0014

0.0003960.018

0.000410.0003240.002030.015121.72821.6

3.78e-07

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)

Equipment Loading-UnloadingEquipment

EQUI19 EU001Tank Truck Bottom Load - MPLw/Vapor Combustor Control

is controlledby

TREA6 100 099-Other 1/12/1998 Null

sends to STRU1 100 Stack/Vent 1/12/1998 Null

EQUI20 EU002Tank Truck Bottom Load - Flint HillsResources (FHR) w/Vapor CombustorControl

is controlledby

TREA7 100 099-Other 1/12/1998 Null

sends to STRU2 100 Stack/Vent 1/12/1998 Null

SI - SI relationships


Details for:SI Category: EquipmentSI Type: Loading-Unloading Equipment

Subject ItemTypeDescription Subject Item ID SI Designation and Description Capacity (gal)Substance Stored

ColumnDiameter (ft)

Number ofColumns Deck Type

InteriorDiameter (ft)

InteriorHeight (ft)

MaximumTrue VaporPressure(psia)

ConstructionType Seal Type Support Type

AbovegroundStorage Tank

EQUI38TK020Gasoline / 3,041,766 gallons / T..

3041766Gasoline Blends(E1-E49)

1 16Bolted, detailsnot specified

120 40 11InternalFloating Roof

Resilient; vapormounted primary only

Column, constructiontype not specified









1 16 Welded 120 40 11InternalFloating Roof

Mechanical; primaryseal only


EQUI49TK001Gasoline / 236,628 gallons / Tan..


Null Null Welded 33 37 11InternalFloating Roof


Self, fixed roof w/ointernal columns

EQUI50TK002Ethanol / 420,420 gallons / Tan..

420420 Other Null Null Welded 48 35 11InternalFloating Roof






















EQUI55TK007Fuel Oil #2 / 1,129,842 gallons /..


















































3297420 Other Null Null Null 120 40 0.1 Fixed Roof Null Null



EQUI69TK019Ethanol / 3,042,060 gallons / Ta..

3042060 Other 1 11Bolted, detailsnot specified












EQUI74TK025Jet kerosene / 3,304,098 gallon..

3304098Jet Fuel(unspecified)

Null Null Null 120 40 0.1 Fixed Roof Null Null









EQUI78TK030Jet kerosene / 3,304,308 gallon..

3304308Jet Fuel(unspecified)

Null Null Null 120 40 0.1 Fixed Roof Null Null





1 16 Welded 120 40 11InternalFloating Roof






208950Ethanol (EthylAlcohol)

Null Null Null 41 27 11 Other Null Null

Aboveground Storage Tanks, General


Details for:SI Category: EquipmentSI Type: Aboveground Storage Tank

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

Loading-UnloadingEquipment

EQUI19EU001Tank Truck Bottom Load - MPL w/VaporCombustor Control

John Zink GV-ZTOF-8500-296000 gallons hours Diesel Fuel 12/12/1994 5/23/1995 Null

EQUI20EU002Tank Truck Bottom Load - Flint HillsResources (FHR) w/Vapor Combustor Cont..

John Zink GV-ZTOF-8500-296000 gallons hours Diesel Fuel 5/16/1994 1/9/1995 Null

Emission Units 1


Details for:SI Category: NoneSI Type: Loading-Unloading Equipment

Subject Item TypeDescription Subject Item ID SI Designation and Description Install Year Pollutants Emitted

Equipment Leaks FUGI1FS001Valves, Pump Seals, Flanges & Connectors.

1940 Volatile Organic Compounds

Fugitive Sources


Details for:SI Category: FugitiveSI Type: Equipment Leaks

Subject ItemTypeDescription Subject Item ID SI Designation and Description Height

Units(height) Length

Units(length) Width

Units(width)

Building STRU4NullTerminal Office

15 feet 105 feet 40 feet

STRU5NullShop/Lab


STRU6NullRail & Ethanol Controls


STRU7NullWarehouse


STRU8NullRack Canopy


STRU9NullRail Canopy


STRU10NullStation


STRU11NullChange Room


STRU12NullPump Shelter


STRU13NullMPL Additive


STRU14NullFHR Additive


STRU15NullPreCard




STRU17NullStorage (Tan)


STRU18NullTech Shop - Terminal


STRU19NullMPL Driver Building


STRU20NullFHR Driver Building


STRU21NullBiodiesel Offload


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)

FlowRate/TempInformationSource Discharge Direction

Stack/Vent STRU1SV001Stack/Vent

45 7.5 Null Null 1136 1400 EstimateUpwards with no cap onstack/vent


45 7.5 Null Null 1136 1400 EstimateUpwards with no cap onstack/vent

Stack/Vent, General


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

Subject ItemTypeDescription Subject Item ID SI Designation and Description Manufacturer Model

InstallationStart Date

PollutantControlled

CaptureEfficiency(%)

Destruction CollectEfficiency (%)

Subject toCAM?

Large orOther PSEU?

EfficiencyBasis

Otheroperatingparameters?

Other operatingparametersdescription

099-Other TREA6CE001Vapor Combustion Unit (VCU)

John Zink GT-ZTO..1/1/1990Volatile OrganicCompounds

98.7 92 Yes Other Test data No Null


John Zink GT-ZTO..1/1/1994Volatile OrganicCompounds

98.7 97 Yes Other Test data No Null

Other Control Equipment


Details for:SI Category: TreatmentSI Type: 099-Other

Subject Item ID Seq. # Requirement Citation

TFAC 1

(12300070) 1

Permit Appendix: This permit contains an appendix as listed in the permit Table of Contents. The

Permittee shall comply with all requirements contained in Appendix A: Insignificant Activities and General

Applicable Requirements. Minn. R. 7007.0800, subp. 2

TFAC 1

(12300070) 2

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

(12300070) 3

These requirements apply if a reasonable possibility (RP) as defined in 40 CFR Section 52.21(r)(6)(vi) exists

that a proposed project, analyzed using the actual‐to‐projected‐actual (ATPA) test (either by itself or as

part of the hybrid test at Section 52.21(a)(2)(iv)(f)) and found to not be part of a major modification, may

result in a significant emissions increase (SEI). If the ATPA test is not used for the project, or if there is no

RP that the proposed project could result in a SEI, these requirements do not apply to that project. The

Permittee is only subject to the Preconstruction Documentation requirement for a project where a RP

occurs only within the meaning of Sec on 52.21(r)(6)(vi)(b).

Even though a particular modification is not subject to New Source Review (NSR), or where there isn't a RP

that a proposed project could result in a SEI, a permit amendment, recordkeeping, or notification may still

be required by Minn. R. 7007.1150 ‐ 7007.1500.

Minn. R. 7007.0800, subp. 2,

Title I Condition: 40 CFR

52.21(r)(6) and Minn. R.

7007.3000

TFAC 1

(12300070) 5

Preconstruction Documentation ‐‐ Before beginning actual construction on a project, the Permittee shall

document the following:

1. Project descrip on

2. Iden fica on of any emission unit whose emissions of an NSR pollutant could be affected

3. Pre‐change potential emissions of any affected existing emission unit, and the projected post‐change

poten al emissions of any affected exis ng or new emission unit.

4. A description of the applicability test used to determine that the project is not a major modification for

any regulated NSR pollutant, including the baseline actual emissions, the projected actual emissions, the

amount of emissions excluded due to increases not associated with the modification and that the

emission unit could have accommodated during the baseline period, an explanation of why the amounts

were excluded, and any creditable contemporaneous increases and decreases that were considered in the

determina on.

The Permittee shall maintain records of this documentation.

Minn. R. 7007.0800, subps. 4‐5,

Minn. R. 7007.1200, subp. 4,


52.21(r)(6) and Minn. R.

7007.3000

TFAC 1

(12300070) 9

The Permittee shall monitor the actual emissions of any regulated NSR pollutant that could increase as a

result of the project and that were analyzed using the ATPA test, and the potential emissions of any

regulated NSR pollutant that could increase as a result of the project and that were analyzed using

potential emissions in the hybrid test. The Permittee shall calculate and maintain a record of the sum of

the actual and potential (if the hybrid test was used in the analysis) emissions of the regulated pollutant,

in tons per year on a calendar year basis, for a period of 5 years following resumption of regular

operations after the change, or for a period of 10 years following resumption of regular operations after

the change if the project increases the design capacity of or potential to emit of any unit associated with

the project.

Minn. R. 7007.0800, subps. 4‐5,


52.21(r)(6) and Minn. R.

7007.3000

TFAC 1

(12300070) 10

The Permittee must submit a report to the Agency if the annual summed (actual, plus potential if used in

hybrid test) emissions differ from the preconstruction projection and exceed the baseline actual emissions

by a significant amount as listed at 40 CFR Section 52.21(b)(23). Such report shall be submitted to the

Agency within 60 days a er the end of the year in which the exceedances occur. The report shall contain:

a. The name and ID number of the Facility, and the name and telephone number of the Facility contact

person.

b. The annual emissions (actual, plus potential if any part of the project was analyzed using the hybrid

test) for each pollutant for which the preconstruction projection and significant emissions increase are

exceeded

c. Any other information, such as an explanation as to why the summed emissions differ from the

preconstruction projection.

Minn. R. 7007.0800, subps. 4‐5,


52.21(r)(6) and Minn. R.

7007.3000


TFAC 1

(12300070) 11

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

pt. 50, and the Minnesota Ambient Air Quality Standards, Minn. R. 7009.0010 to 7009.0080. Compliance

shall be demonstrated upon written request by the MPCA.

Minn. R. 7007.0100, subp. 7(A),

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

7007.0800, subp. 4, Minn. R.

7007.0800, subps. 1‐2, Minn. R.

7009.0010‐7009.0080, Minn.

Stat. 116.07, subd. 4a, Minn.

Stat. 116.07, subd. 9

TFAC 1

(12300070) 12

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

(12300070) 16

Air Pollution Control Equipment: Operate all pollution control equipment whenever the corresponding

process equipment and emission units are operated.

Minn. R. 7007.0800, subp. 16(J),

Minn. R. 7007.0800, subp. 2

TFAC 1

(12300070) 17

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

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

equipment and control practices and shall include a preventative maintenance program for the

equipment and practices, a description of (the minimum but not necessarily the only) corrective actions to

be taken to restore the equipment and practices to proper operation to meet applicable permit

conditions, a description of the employee training program for 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

(12300070) 18

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

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

Commissioner may require feasible and practical modifications in the operation to reduce emissions of air

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

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

TFAC 1

(12300070) 19

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

manner which may allow avoidable amounts of particulate matter to become airborne. Comply with all

other requirements listed in Minn. R. 7011.0150. Minn. R. 7011.0150

TFAC 1

(12300070) 20

Noise: The Permittee shall comply with the noise standards set forth in Minn. R. 7030.0010 to 7030.0080

at all times during the operation of any emission units. This is a state only requirement and is not

enforceable by the EPA Administrator or citizens under the Clean Air Act. Minn. R. 7030.0010‐7030.0080

TFAC 1

(12300070) 21

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

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

TFAC 1

(12300070) 22 The Permittee shall comply with the General Conditions listed in Minn. R. 7007.0800, subp. 16. Minn. R. 7007.0800, subp. 16

TFAC 1

(12300070) 23

Emergency Provisions: The affirmative defense of emergency shall be demonstrated through properly

signed, contemporaneous operating logs and other relevant data in accordance with Minn. R. 7007.1850. Minn. R. 7007.1850

TFAC 1

(12300070) 24

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

(12300070) 25

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

(12300070) 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

(12300070) 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

(12300070) 28

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

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

expiring permits, these records shall be kept for a period of five years from the date the change was made

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

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

source for all other years. The records may be maintained in either electronic or paper format. Minn. R. 7007.1200, subp. 4

TFAC 1

(12300070) 29

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

(12300070) 33

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

(12300070) 36

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

(12300070) 37

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

(12300070) 38

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

(12300070) 39

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

(12300070) 40

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

any control equipment or process equipment if the shutdown would cause any increase in the emissions

of any regulated air pollutant. If the owner or operator does not have advance knowledge of the

shutdown, notification shall be made to the Commissioner as soon as possible after the shutdown.

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

7019.1000, subp. 3.

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

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

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

TFAC 1

(12300070) 41

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

duration of any control equipment or process equipment if the breakdown causes any increase in the

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

discovered or reasonably should have been discovered by the owner or operator. However, notification is

not required in the circumstances outlined in Items A, B and C of Minn. R. 7019.1000, subp. 2.

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

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

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

TFAC 1

(12300070) 42

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

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

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


TFAC 1

(12300070) 43

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

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

endanger human health or the environment. Include the following informa on in this wri en 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

(12300070) 45

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

(12300070) 47

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

(12300070) 48

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

(12300070) 49 Emission Fees: due 30 days after receipt of an MPCA bill. Minn. R. 7002.0005‐7002.0095

COMG 3

1

This facility meets the definition of an existing bulk gasoline terminal: a gasoline storage and distribution

facility that receives gasoline by pipeline and has a gasoline throughput of 20,000 gallons per day or

greater. Gasoline throughput shall be the maximum calculated design throughput as defined at 40 CFR

Section 63.11100. The Permittee shall comply with the following standards in 40 CFR pt. 63, subp.

BBBBBB.

40 CFR 63.11081(a)(1), 40 CFR

63.11082(d)

COMG 3

2

40 CFR pt. 63, subp. BBBBBB is an Applicable Requirement under Minn. R. 7007.0100, subp. 7(D);

however, this standard is not delegated to MPCA. Minn. R. 7007.0100, subp. 7(D)

COMG 3

3

For each gasoline storage tank with a capacity of greater than or equal to 75 cubic meters, the Permittee

must:

(1) Equip each internal floating roof gasoline storage tank according to the requirements in 40 CFR Section

60.112b(a)(1), except for the secondary seal requirements under 40 CFR Section 60.112b(a)(1)(ii)(B) and

the requirements in 40 CFR Sec on 60.112b(a)(1)(iv) through (ix); AND

(2) Equip each external floating roof gasoline storage tank according to the requirements in 40 CFR Section

60.112b(a)(2), except that the requirements of 40 CFR Section 60.112b(a)(2)(ii) shall only be required if

such storage tank does not currently meet the requirements of 40 CFR Sec on 60.112b(a)(2)(i); OR

(3) Equip and operate each internal and external floating roof gasoline storage tank according to the

applicable requirements in 40 CFR Section 63.1063(a)(1) and (b), except for the secondary seal

requirements under 40 CFR Section 63.1063(a)(1)(I)(C) and (D), and equip each external floating roof

gasoline storage tank according to the requirements of 40 CFR Section 63.1063(a)(2) if such storage tank

does not currently meet the requirements of 40 CFR Sec on 63.1063(a)(1).

For any gasoline storage tanks with a capacity of greater than or equal to 75 cubic meters equipped with

floating roofs that do not meet the requirements of 40 CFR Section 63.11087(a), the Permittee shall

ensure that the storage tanks are in compliance at the first degassing and cleaning activity after January

10, 2011, or by January 10, 2018, whichever is first. The Permittee shall submit final verification of control

equipment for affected tanks prior to January 10, 2018.

40 CFR 63.11087(a), 40 CFR

63.11087(b)

COMG 3

4

For each gasoline surge control tank, the Permittee shall equip each with a fixed roof that is mounted to

the tank in a stationary manner and with a pressure/vacuum vent with a positive cracking pressure of no

less than 0.50 inches of water. Maintain all openings in a closed position at all times when not in use. 40 CFR 63.11087(a)


COMG 3

5

For all gasoline loading rack(s), the Permi ee shall:

(a) Equip the loading rack(s) with a vapor collection system designed to collect the TOC vapors displaced

from cargo tanks during product loading;

(b) Reduce emissions of TOC to less than or equal to 80 mg/l of gasoline loaded into gasoline cargo tanks

at the loading rack;

(c) Design and operate the vapor collection system to prevent any TOC vapors collected at one loading

rack from passing to another loading rack; and

(d) Limit the loading of gasoline into gasoline cargo tanks that are vapor tight using the procedures

specified in 40 CFR Section 60.502(e) through (j). For the purposes of this item, the term "tank truck" as

used in 40 CFR Section 60.502(e) through (j) means "cargo tank" as defined in 40 CFR Section 63.11100. 40 CFR 63.11088(a)

COMG 3

7

Circumvention. The Permittee shall not build, erect, install, or use any article, machine, equipment, or

process to conceal an emission that would otherwise constitute noncompliance with a relevant standard.

Such concealment includes, but is not limited to:

(1) The use of diluents to achieve compliance with a relevant standard based on the concentration of a

pollutant in the effluent discharged to the atmosphere; or

(2) The use of gaseous diluents to achieve compliance with a relevant standard for visible emissions.

40 CFR 63.4(b), Minn. R.

7011.7000

COMG 3

8

Proper Operation and Maintenance: At all times, including periods of startup, shutdown and malfunction,

the Permittee shall operate and maintain the emission units subject to NESHAP BBBBBB and its associated

air pollution control and monitoring equipment in a manner consistent with safety and good air pollution

control practices for minimizing emissions at least to the levels required by all relevant standards.

Determination of whether such operation and maintenance procedures are being used will be based on

information available to the Administrator, which may include, but is not limited to, monitoring results,

review of operation and maintenance procedures, review of operation and maintenance records, and

inspection of the source.

40 CFR 63.11085(a), 40 CFR

63.6(e)(1)(i), Minn. R.

7011.7000

COMG 3

9

The Permittee shall:

(1) Operate the vapor processing system in a manner not to exceed or not to go below, as appropriate,

the operating parameter value for the parameters described in 40 CFR Section 63.11092(b)(1).

(2) Operation of the vapor processing system in a manner exceeding or going below the operating

parameter value, as appropriate, shall constitute a violation of the emission standard in 40 CFR Section

63.11088(a), except as specified in 40 CFR Section 63.11092(d)(4). 40 CFR 63.11092(d)(1) and (3)

COMG 3

10

Each loading rack's thermal oxidation system pilot flame shall be monitored using a heat‐sensing device,

such as a thermocouple, installed in proximity to the pilot light to indicate the presence of a flame. The

heat‐sensing device shall send a positive parameter value to indicate that the pilot flame is on, or a

negative parameter value to indicate that the pilot flame is off.

40 CFR 63.11088(d), 40 CFR

63.11092(a), 40 CFR

63.11092(b)(1)(iii)(B)(1)

COMG 3

12

The Permittee shall determine an operating parameter value based on the parameter data monitored

during the performance test, supplemented by engineering assessments and the manufacturer's

recommenda ons.

The Permittee shall Provide for the Administrator's approval the rationale for the selected operating

parameter value, monitoring frequency, and averaging time, including data and calculations used to

develop the value and a description of why the value, monitoring frequency, and averaging time

demonstrate continuous compliance with the emission standard in 40 CFR Section 63.11088(a). 40 CFR 63.11092(b)(3) and (4)

COMG 3

13

Monthly Leak Inspections: The Permittee shall perform a monthly leak inspection of all equipment in

gasoline service, as defined in 40 CFR Section 63.11100. For this inspection, detection methods

incorpora ng sight, sound, and smell are acceptable.

40 CFR Section 63.11100 defines 'in gasoline service' as a piece of equipment used in a system that

transfers gasoline or gasoline vapors and 'monthly' as once per calendar month at regular intervals of no

less than 28 days and no more than 35 days.

40 CFR 63.11089(a), 40 CFR

63.11100

COMG 3

14

For each gasoline storage tank equipped with an internal floating roof, the Permittee must perform

inspec ons of the floa ng roof system according to:

‐ the requirements of Section 60.113b(a) if complying with option 2(b) in Table 1 of 40 CFR pt. 63, subp.

BBBBBB; OR

‐ the requirements of Section 60.1063(c)(1) if complying with option 2(d) in Table 1 of 40 CFR pt. 63, subp.

BBBBBB. 40 CFR 63.11092(e)(1)

COMG 3

16

For all gasoline loading rack(s), the Permittee shall install, calibrate, certify, operate, and maintain,

according to the manufacturer's specifications, a continuous monitoring system (CMS) while gasoline

vapors are displaced to the vapor processor systems.

40 CFR 63.11088(d), 40 CFR

63.11092(b)

COMG 3

17 Malfunctions shall be corrected as soon as practicable after their occurrence.

40 CFR 63.6(e)(1)(ii), Minn. R.

7011.7000


COMG 3

18

For the monitoring and inspection, as required under 40 CFR Section 63.11092(b)(1)(iii)(B)(2),

malfunctions that are discovered shall not constitute a violation of the emission standard in 40 CFR

Section 63.11088(a) if corrective actions as described in the monitoring and inspection plan are followed.

The Permi ee must:

(i) Ini ate correc ve ac on to determine the cause of the problem within 1 hour;

(ii) Ini ate correc ve ac on to fix the problem within 24 hours;

(iii) Complete all corrective actions needed to fix the problem as soon as practicable consistent with good

air pollu on control prac ces for minimizing emissions;

(iv) Minimize periods of start‐up, shutdown, or malfunc on; and

(v) Take any necessary corrective actions to restore normal operation and prevent the recurrence of the

cause of the problem. 40 CFR 63.11092(d)(4)

COMG 3

19

Leak Inspection Recordkeeping: A log book shall be used and shall be signed by the Permittee at the

completion of each inspection. A section of the log book shall contain a list, summary description, or

diagram(s) showing the location of all equipment in gasoline service at the facility. 40 CFR 63.11089(b)

COMG 3

20

The Permittee shall prepare and maintain a record describing the types, identification numbers, and

locations of all equipment in gasoline service. 40 CFR 63.11094(d)

COMG 3

21

The Permi ee shall record in the log book for each leak that is detected the informa on specified below:

(1) The equipment type and iden fica on number.

(2) The nature of the leak (i.e. vapor or liquid) and the method of detec on (i.e. sight, sound, or smell).

(3) The date the leak was detected and the date of each a empt to repair the leak.

(4) Repair methods applied in each a empt to repair the leak.

(5) A statement of: Repair Delayed and the reason for the delay if the leak is not repaired within 15

calendar days a er discovery of the leak.

(6) The expected date of successful repair of the leak if the leak is not repaired within 15 days.

(7) The date of successful repair of the leak. 40 CFR 63.11094(e)

COMG 3

22

Each detection of a liquid or vapor leak shall be recorded in the log book. When a leak is detected, an

initial attempt at repair shall be made as soon as practicable but no later than 5 calendar days after the

leak is detected. Repair or replacement of leaking equipment shall be completed within 15 calendar days

after detection of each leak, except as provided in the requirement listed below (referring to 40 CFR

Section 63.11089(d)). 40 CFR 63.11089(c)

COMG 3

23

The Permi ee shall:

(1) Keep an up‐to‐date, readily accessible record of the continuous monitoring data required under 40 CFR

Section 63.11092(b). This record shall indicate the time intervals during which loadings of gasoline cargo

tanks have occurred or, alternatively, shall record the operating parameter data only during such loadings.

The date and me of day shall also be indicated at reasonable intervals on this record.

(3) Keep an up‐to‐date, readily accessible copy of the monitoring and inspection plan required under 40

CFR Sec on 63.11092(b)(1)(iii)(B)(2).

(4) Keep an up‐to‐date, readily accessible record of all system malfunctions, as specified in 40 CFR Section

63.11092(b)(1)(iii)(B)(2)(v).

40 CFR 63.11088(f), 40 CFR

63.11094(f)(1), (3), and (4)


COMG 3

25

The Permittee shall maintain a monitoring and inspection plan that describes the Permittee's approach for

meeting the following requirements. If any monitoring and inspection procedures change, the Permittee

shall submit to the Administrator the updated approach for mee ng the following requirements:

1) The Permittee shall equip TREA 6 and TREA 7 to automatically prevent gasoline loading operations at

EQUI 19 and EQUI 20 from starting up at any time that the pilot flame is absent. TREA 6 and TREA 7 shall

also automatically shutdown loading operations if the pilot flame goes out during loading, and TREA 6 and

TREA 7 shall not allow loading to resume un l the pilot flame is present.

2) The Permittee shall verify, during each day of operation of EQUI 19, EQUI 20, TREA 6 and TREA 7, the

proper operation of the assist‐air blower, the vapor line valve, and the emergency shutdown system.

Verification shall be through visual observation or through an automated alarm or shutdown system that

monitors and records system operation. A manual or electronic record of the start and end of a shutdown

event may be used.

3) The Permittee shall perform semi‐annual preventive maintenance inspections of EQUI 19, EQUI20, TREA

6, and TREA 7, including the automated alarm or shutdown system for those units so equipped, according

to the recommenda ons of the manufacturer of the system.

4) The monitoring and inspection plan shall specify conditions that would be considered malfunctions of

EQUI 19, EQUI 20, TREA 6, and/or TREA 7 during the inspections or automated monitoring performed

under 40 CFR Section 63.11092(b)(1)(iii)(B)(2)(ii) and (iii), describe specific corrective actions that will be

taken to correct any malfunction, and define what the Permittee would consider to be a timely repair for

each poten al malfunc on.

5) The Permittee shall document any malfunction of EQUI 19, EQUI 20, TREA 6 or TREA 7, as defined in the

monitoring and inspection plan, and any activation of the automated alarm or shutdown system with a

written entry into a log book or other permanent form of record. Such record shall also include a

description of the corrective action taken and whether such corrective actions were taken in a timely

manner, as defined in the monitoring and inspection plan, as well as an estimate of the amount of

gasoline loaded during the period of the malfunction.

40 CFR 63.11088(d), 40 CFR

63.11092(a), 40 CFR

63.11092(b)(1)(iii)(B)(2)

COMG 3

26

The Permittee shall keep records of the test results for each gasoline cargo tank loading at the facility as

specified below:

(1) Annual cer fica on tes ng performed under 40 CFR Sec on 63.11092(f)(1).

(2) The documentation file shall be kept up‐to‐date for each gasoline cargo tank loading at the facility. The

documentation for each test shall include the information specified in 40 CFR Section 63.11094(b)(2).

40 CFR 63.11088(f), 40 CFR

63.11094(b)

COMG 3

27

As an alternative to keeping records of each gasoline cargo tank test result at the terminal, as required in

40 CFR Sec on 63.11094(b), the Permi ee may comply with the requirements of paragraph 1 or 2, below:

(1) An electronic copy of each record is instantly available at the terminal, and the electronic copy of each

record shall be an exact duplicate image of the original paper record with certifying signatures. If this

option is chosen, the Permittee shall notify the Administrator in writing that the terminal using this

alterna ve in compliance with 40 CFR Sec on 63.11094(c)(1).

(2) For facilities that use a terminal automation system (TAS) to prevent gasoline cargo tanks that do not

have valid cargo tank vapor tightness documentation from loading (e.g., via a card lock‐out system), a

copy of the documentation is made available (e.g., via facsimile) for inspection by the Administrator's

delegated representatives during the course of a site visit, or within a mutually agreeable time frame. The

copy of each record shall be an exact duplicate image of the original paper record with certifying

signatures. If this option is chosen, the Permittee shall notify the Administrator in writing that the terminal

using this alternative in compliance with 40 CFR Section 63.11094(c)(2).

40 CFR 63.11088(f), 40 CFR

63.11094(c)

COMG 3

28

The Permi ee shall keep the following records:

1) Records of the occurrence and duration of each malfunction of operation (i.e., process equipment) or

the air pollu on control and monitoring equipment.

2) Records of actions taken during periods of malfunction to minimize emissions in accordance with 40

CFR Section 63.11085(a), including corrective actions to restore malfunctioning process and air pollution

control and monitoring equipment to its normal or usual manner of operation. 40 CFR 63.11094(g)


COMG 3

30

The Permi ee shall maintain, at a minimum, the following informa on in the files:

1) the occurrence and duration of each startup, shutdown, or malfunction of operation when the startup

or shutdown causes the source to exceed any applicable emission limitation in the relevant emission

standards;

2) the occurrence and duration of each malfunction of operation (i.e., process equipment) or the required

air pollu on control and monitoring equipment;

3) all maintenance performed on the air pollu on control and monitoring equipment;

4) actions taken during periods of startup, shutdown, and malfunction when such actions are different

from the procedures specified in the affected source's startup, shutdown, and malfunction plan (SSMP). In

this case, the Permittee shall report this action within 2 days of occurrence and follow by a written

no fica on within 7 days of occurrence;

5) all information necessary to demonstrate conformance with the affected source's SSMP and actions

taken in accordance with SSMP;

6) each period during which a con nuous monitoring system (CMS) is malfunc oning or inopera ve;

7) all required measurements needed to demonstrate compliance with a relevant standard;

8) all results of performance test, CMS performance evaluations, and opacity and visible emission

observa ons;

9) all measurements as may be necessary to determine the conditions of performance tests and

performance evalua ons;

10) all CMS calibra on checks;

11) all adjustments and maintenance performed on CMS;

12) any information demonstrating whether a source is meeting the requirements for a waiver of record

keeping or repor ng requirements under this part;

13) All emission levels relative to the criterion for obtaining permission to use an alternative to the relative

accuracy test, if the source has been granted such permission under 40 CFR 63.8(f)(6); and

14) all documentation supporting initial notifications and notifications of compliance status.

40 CFR 63.10(b)(2), Minn. R.

7019.0100, subp. 2(B)

COMG 3

31

Recordkeeping: The Permittee shall maintain files of all information required by 40 CFR pt. 63 in a form

suitable and readily available for expedi ous inspec on and review.

The files should be retained for at least 5 years following the date of each occurrence, measurement,

maintenance, corrective action, report, or record. Only the most recent two years of information must be

kept on site.

40 CFR 63.10(b)(1), Minn. R.

7019.0100, subp. 2(B)

COMG 3

32

The Permittee shall keep records as specified in 40 CFR Section 63.1065. The Permittee shall keep records

as specified in 40 CFR Section 63.1065(a) for as long as liquid is stored and 63.1065(b)‐(d) for at least 5

years.

40 CFR 63.1065, 40 CFR

63.11094(a)

COMG 3

33

For performance tests performed after the initial test required by 40 CFR Section 63.11092(a), the

Permittee shall document the reasons for any change in the operating parameter value since the previous

performance test. 40 CFR 63.11092(c)

COMG 3

34

For each performance test conducted under 40 CFR Section 63.11092(a)(1), the Permittee shall determine

a monitored operating parameter value for the vapor processing system using the procedures specified

below. During the performance test, the Permittee shall continuously record the operating parameter as

specified below. 40 CFR 63.11092(b)

COMG 3

35

The annual certification test for each gasoline cargo tank shall consist of the test methods specified in 40

CFR Section 63.11092(f)(1) or (2). Facilities that are also subject to 40 CFR pt. 60, subp. XX may elect, after

notification to the MPCA, to comply with 40 CFR Section 63.11092(f)(1) or (2). 40 CFR 63.11092(f)

COMG 3

37

Delay of Equipment Leak Repair: Delay of repair of leaking equipment will be allowed if the repair is not

feasible within 15 days. The Permittee shall provide in the semiannual Excess Emissions Report specified in

40 CFR Section 63.11095(b), the reason(s) why the repair was not feasible and the date each repair was

completed. 40 CFR 63.11089(d)


COMG 3

38

The Permittee shall submit a semiannual excess emissions (EER) report to the Administrator with the

Semiannual Deviations Report listed in this permit. Excess emissions events, and the information to be

included in the excess emissions report, are as follows:

(1) Each instance of a non‐vapor‐tight gasoline cargo tank loading at the facility in which the Permittee

failed to take steps to assure that such cargo tank would not be reloaded at the facility before vapor

ghtness documenta on for that cargo tank was obtained.

(2) Each reloading of a non‐vapor‐tight gasoline cargo tank at the facility before vapor tightness

documentation for that cargo tank is obtained by the facility in accordance with 40 CFR Section

63.11094(b).

(3) Each exceedance or failure to maintain, as appropriate, the monitored operating parameter value

determined under 40 CFR Section 63.11092(b). The report shall include the monitoring data for the days

on which exceedances or failures to maintain have occurred, and a description and timing of the steps

taken to repair or perform maintenance on the vapor collec on and processing systems or the CMS.

(4) Each instance in which malfunctions discovered during the monitoring and inspections required under

40 CFR Section 63.11092(b)(1)(i)(B)(2) and (iii)(B)(2) were not resolved according to the necessary

corrective actions described in the monitoring and inspection plan. The report shall include a description

of the malfunc on and the ming of the steps taken to correct the malfunc on.

(5) For each occurrence of an equipment leak for which no repair attempt was made within 5 days or for

which repair was not completed within 15 days a er detec on:

(i) The date on which the leak was detected;

(ii) The date of each a empt to repair the leak;

(iii) The reasons for the delay of repair; and

(iv) The date of successful repair. 40 CFR 63.11095(b)

COMG 3

39

The Permittee shall submit a semiannual report including the number, duration, and a brief description of

each type of malfunction which occurred during the reporting period and which caused or may have

caused any applicable emission limitation to be exceeded. The report must also include a description of

actions taken by the Permittee during a malfunction to minimize emissions in accordance with 40 CFR

Section 63.11085(a), including actions taken to correct a malfunction. The report may be submitted as a

part of the semiannual compliance report. 40 CFR 63.11095(d)

COMG 3

40

The Permittee shall also include the following in the Semiannual Deviations Report (listed elsewhere in

this permit), as applicable:

1) For storage vessels complying with option 2(a), 2(b), or 2(c) in Table 1 of 40 CFR pt. 63, subp. BBBBBB,

the information specified in 40 CFR Section 60.115b(a), 60.115b(b), or 60.115b(c), depending upon the

control equipment installed, or, if you are complying with option 2(d) in Table 1 of 40 CFR pt. 63, subp.

BBBBBB, the informa on specified in 40 CFR Sec on 63.1066;

2) For loading racks, each loading of a gasoline cargo tank for which vapor tightness documentation had

not been previously obtained by the facility;

3) For equipment leak inspections, the number of equipment leaks not repaired within 15 days after

detec on; and

4) For storage vessels complying with 40 CFR Section 63.11087(b) after January 10, 2011, the storage

vessel’s Notice of Compliance Status Information can be included in the next semi‐annual compliance

report in lieu of filing a separate Notification of Compliance Status report under 40 CFR Section 63.11093.

40 CFR 63.11087(e), 40 CFR

63.11089(g), 40 CFR

63.11095(a)

COMG 3

41

After the effective date of any relevant standard promulgated by the Administrator under 40 CFR pt. 63,

equipment added (or a process change) to an affected source that is within the scope of the definition of

affected source under the relevant standard must be considered part of the affected source and subject to

all provisions of the relevant standard established for that affected source.

40 CFR 63.5(b), Minn. R.

7011.7000

COMG 3

44

Prior to construction or reconstruction of a major‐emitting "affected source" under the promulgated

MACT standards, the Permittee must apply for and obtain an air emission permit.

40 CFR 63.5(b)(3)& Minn. R.

7011.7000

EQUI 19

(EU001) 1 Total Organic Compounds <= 35 milligrams per liter of gasoline loaded.

40 CFR 60.502(b), Minn. R.

7011.1550

EQUI 19

(EU001) 2

The Permittee shall operate and maintain EQUI 19's vapor collection system such that it achieves an

overall capture efficiency for Total Organic Compounds >= 98.7 percent capture efficiency.

Minn. R. 7007.0800,

subps.2&14

EQUI 19

(EU001) 3

Design Requirement: The vapor collection and liquid loading equipment shall be designed and operated to

prevent gauge pressure in the delivery tank from exceeding 4,500 pascals (450 mm of water) during

product loading. This level is not to be exceeded when measured by the procedures specified in 40 CFR

Section 60.503(d).

40 CFR 60.502(h), 40 CFR 64.3,

Minn. R. 7011.1550, Minn. R.

7017.0200

EQUI 19

(EU001) 4

Gauge Pressure Requirement: No pressure‐vacuum vent in the bulk gasoline terminal's vapor collection

system shall begin to open at a system pressure less than 4,500 pascals (450 mm of water).

40 CFR 60.502(i), 40 CFR 64.3,

Minn. R. 7011.1550, Minn. R.

7017.0200


EQUI 19

(EU001) 5

Loadings: Loadings of liquid product into gasoline tank trucks shall be limited to vapor‐tight gasoline tank

trucks using the following procedures. The Permi ee shall:

1. Obtain the vapor tightness documentation described in 40 CFR Section 60.505(b) for each gasoline tank

truck which is to be loaded at the facility.

2. Require the tank identification number to be recorded as each gasoline tank truck is loaded at the

facility.

3. Cross‐check each tank identification number with the file of tank vapor tightness documentation within

2 weeks a er the corresponding tank is loaded.

4. Notify the owner or operator of each nonvapor‐tight gasoline tank truck loaded at the facility within 1

week a er the documenta on cross‐check (in #3) has occurred.

5. Take steps assuring that the non‐vapor‐tight gasoline tank truck will not be reloaded at the facility until

vapor ghtness documenta on for that tank is obtained.

6. Alternate procedures may be used upon application to, and approval by, the Administrator.

40 CFR 60.502(e), Minn. R.

7011.1550

EQUI 19

(EU001) 6

The Permittee shall operate the vapor combustion unit (VCU, TREA 6) during loading to control emissions

from the Bottom Loading Rack (EQUI 19). The Permittee shall document periods of non‐operation of the

control equipment. Minn. R. 7007.0800, subp. 14

EQUI 19

(EU001) 7

Operation Requirement: The Permittee shall act to assure that loadings of gasoline tank trucks at the

facility are made only into tanks equipped with vapor collection equipment that is compatible with the

terminal's vapor collection system.

40 CFR 60.502(f), Minn. R.

7011.1550

EQUI 19

(EU001) 8

Operation Requirement: The Permittee shall act to assure that the terminal's and the tank truck's vapor

collection systems are connected during each loading of a gasoline tank truck at the affected facility. This

includes training drivers in the hookup procedures and posting visible reminder signs at the affected

loading racks.

40 CFR 60.502(g), Minn. R.

7011.1550

EQUI 19

(EU001) 9

Operation Requirement: At all times, including periods of startup, shutdown, and malfunction, owners

and operators shall maintain and operate any affected facility including associated air pollution control

equipment in a matter consistent with good air pollution control practice for minimizing emissions.

Determination of whether acceptable operating and maintenance procedures are being used will be

based on information which may include, but is not limited to, monitoring results, opacity observations,

review of operating and maintenance procedures, and inspection.

40 CFR 60.11(d), Minn. R.

7017.2015

EQUI 19

(EU001) 10

Operation and Maintenance (O & M) Plan: The Permittee shall operate and maintain the VCU in

accordance with the facility O & M Plan and the control equipment manufacturer's specifications. The

Permittee shall keep copies of the O & M Plan available onsite for use by staff and MPCA staff.

40 CFR 64.8, Minn. R.

7007.0800, subp. 14, Minn. R.

7017.0200

EQUI 19

(EU001) 11

Monthly Inspections: Each calendar month the vapor collection system, the vapor processing system, and

each loading rack handling gasoline shall be inspected during the loading of gasoline tank trucks for total

organic compounds liquid or vapor leaks. For purposes of this requirement, detection methods

incorporating sight, sound, or smell are acceptable.

40 CFR 60.502(j), 40 CFR 64.7,

Minn. R. 7011.1550, Minn. R.

7017.0200

EQUI 19

(EU001) 13

Semiannual Inspections: The Permittee shall inspect the VCU at least semiannual and shall maintain a

written record of the inspection and any action resulting from the inspection.

40 CFR 64.3(b)(4), Minn. R.

7007.0800, subp. 14, Minn. R.

7007.0800, subps. 4‐5, Minn. R.

7017.0200

EQUI 19

(EU001) 14

Total Organic Compounds : The Permittee shall conduct a performance test : Due before 09/06/2020

every 36 months to verify the emission factor of total organic compounds (mg/l) and pressure according

to 40 CFR 60.502(h). All subsequent tests are due by the end of each 36‐month period following that date.

Compliance with 40 CFR 60.502(b) shall be determined by complying with 40 CFR 60.503(b)‐(c) and 40 CFR

63.11092(a)(1)(i), and compliance with 40 CFR 60.502(h) shall be determined by complying with 40 CFR

60.503(d). Performance tests required under this condition were completed on November 18, 2002,

September 6, 2007, and August 22, 2012. The performance test shall be conducted at worst case

conditions as defined at Minn. R. 7017.2025, subp. 2, using EPA Reference Method 25A or 25B, or other

method approved by MPCA in the performance test plan approval.

Testing conducted during the 60 days prior to the performance test due date satisfies the performance

test due date, and will not reset the test due date for future tes ng as required:

1. by this permit;

2. by the most recently approved Performance Test Frequency Plan; or

3. within a No ce of Compliance le er.

Testing conducted more than two months prior to the performance test due date satisfies this test due

date requirement and will reset the performance test due date.

40 CFR 60.503(a), 40 CFR

60.8(a), 40 CFR 64.3(c), Minn. R.

7011.1550, Minn. R. 7017.0200,

Minn. R. 7017.2015, Minn. R.

7017.2020, subp. 1

EQUI 19

(EU001) 15

Leak Repairs: Each detection of a leak shall be recorded and the source of the leak repaired within 15

calendar days after it is detected.

40 CFR 60.502(j), 40 CFR 64.7,

Minn. R. 7011.1550, Minn. R.

7017.0200


EQUI 19

(EU001) 16

Corrective Actions: If the gauge pressure in the delivery tank exceeds 4,500 pascals (450 mm of water)

during product loading, the Permittee shall take corrective action as soon as possible according to the

control equipment manufacturer's specifications and the facility operation and maintenance plan. The

Permittee shall keep a log of all corrective actions taken with records entered upon completion of each

corrective action.

40 CFR 64.7(d)(1), Minn. R.

7017.0200

EQUI 19

(EU001) 17

Recordkeeping: The documentation file for each gasoline tank truck shall be updated at least once per

year to reflect current test results as determined by Method 27 or equivalent method approved by MPCA.

Trucks tested in accordance with 40 CFR Section 63.425(a) are considered to meet this requirement. This

documenta on shall include, as a minimum, the following informa on:

1. Test title: Gasoline Delivery Tank Pressure Test ‐EPA Reference Method 27 (or equivalent approved by

MPCA).

2. Tank owner and address.

3. Tank iden fica on number.

4. Tes ng loca on.

5. Date of test.

6. Tester name and signature.

7. Witnessing inspector, if any: Name, signature, and affilia on.

8. Test results: Actual pressure change in 5 minutes, mm of water (average for 2 runs).

40 CFR 60.505(b), Minn. R.

7011.1550

EQUI 19

(EU001) 18

Recordkeeping: The tank truck vapor tightness documentation required under 40 CFR 60.502(e)(1) shall be

kept on file at the terminal in a permanent form available for inspection.

40 CFR 60.505(a), Minn. R.

7011.1550

EQUI 19

(EU001) 19

Inspection Recordkeeping: A record of each monthly leak inspection required under 40 CFR 60.502(j) shall

be kept on file at the terminal for at least five (5) years and shall include, at a minimum, the following

informa on:

1. Date of inspec on.

2. Findings (may indicated no leaks discovered; or loca on, nature, and severity of each leak).

3. Leak determina on method.

4. Correc ve ac on (date each leak repaired, reasons for any repair interval >15 days).

5. Inspector name and signature.

40 CFR 60.505(c), Minn. R.

7007.0800, subp. 5, Minn. R.

7011.1550

EQUI 19

(EU001) 20

Recordkeeping of Notifications: The Permittee shall keep documentation of all notifications required

under 40 CFR Section 60.502(e)(4) on file at the terminal for at least five (5) years.

40 CFR 60.505(d), Minn. R.

7011.1550

EQUI 19

(EU001) 21

Component Recordkeeping: The Permittee shall keep records of all replacements or additions of

components performed on an existing vapor processing system on site for at least five (5) years.

40 CFR 60.505(f), Minn. R.

7011.1550

EQUI 19

(EU001) 22

Recordkeeping: The Permittee shall maintain records of the occurrence and duration of each startup,

shutdown, or malfunction of the VCU.

40 CFR 60.7(b), Minn. R.

7019.0100, subp. 1

EQUI 19

(EU001) 29

Performance Test No fica ons and Submi als;

Performance Test No fica on (wri en): due 30 days before each Performance Test,

Performance Test Plan: due 30 days before each Performance Test,

Performance Test Pre‐Test Mee ng: due 7 day before each Performance Test,

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

Performance Test Report ‐ Microfiche Copy or CD: due 105 day after each Performance Test.

Minn. R. 7017.2030, Minn. R.

7017.2035, subp. 1, Minn. R.

7017.2035, subp. 2

EQUI 19

(EU001) 30

Corrective Actions Reporting: All situations warranting corrective actions are deviations, the Permittee

shall report the deviations in the semiannual deviations report as required in the total facility section of

this permit.

40 CFR 64.9(a)(2)(i), Minn. R.

7017.0200

EQUI 20

(EU002) 1 Total Organic Compounds <= 35 milligrams per liter of gasoline loaded.

40 CFR 60.502(b), Minn. R.

7011.1550

EQUI 20

(EU002) 2

The Permittee shall operate and maintain EQUI 20's vapor collection system such that it achieves an

overall capture efficiency for Total Organic Compounds >= 98.7 percent capture efficiency.

Minn. R. 7007.0800,

subps.2&14

EQUI 20

(EU002) 3

Design Requirement: The vapor collection and liquid loading equipment shall be designed and operated to

prevent gauge pressure in the delivery tank from exceeding 4,500 pascals (450 mm of water) during

product loading. This level is not to be exceeded when measured by the procedures specified in 40 CFR

Section 60.503(d).

40 CFR 60.502(h), 40 CFR 64.3,

Minn. R. 7011.1550, Minn. R.

7017.0200

EQUI 20

(EU002) 4

Gauge Pressure Requirement: No pressure‐vacuum vent in the bulk gasoline terminal's vapor collection

system shall begin to open at a system pressure less than 4,500 pascals (450 mm of water).

40 CFR 60.502(i), 40 CFR 64.3,

Minn. R. 7011.1550, Minn. R.

7017.0200


EQUI 20

(EU002) 5

Loadings: Loadings of liquid product into gasoline tank trucks shall be limited to vapor‐tight gasoline tank

trucks using the following procedures. The Permi ee shall:

1. Obtain the vapor tightness documentation described in 40 CFR Section 60.505(b) for each gasoline tank

truck which is to be loaded at the facility.

2. Require the tank identification number to be recorded as each gasoline tank truck is loaded at the

facility.

3. Cross‐check each tank identification number with the file of tank vapor tightness documentation within

2 weeks a er the corresponding tank is loaded.

4. Notify the owner or operator of each nonvapor‐tight gasoline tank truck loaded at the facility within 1

week a er the documenta on cross‐check (in #3) has occurred.

5. Take steps assuring that the nonvapor‐tight gasoline tank truck will not be reloaded at the facility until

vapor ghtness documenta on for that tank is obtained.

6. Alternate procedures may be used upon application to, and approval by, the Administrator.

40 CFR 60.502(e), Minn. R.

7011.1550

EQUI 20

(EU002) 6

The Permittee shall operate the vapor combustion unit (VCU, TREA 7) during loading to control emissions

from the Bottom Loading Rack (EQUI 20). The Permittee shall document periods of non‐operation of the

control equipment. Minn. R. 7007.0800, subp. 14

EQUI 20

(EU002) 7

Operation Requirement: The Permittee shall act to assure that loadings of gasoline tank trucks at the

facility are made only into tanks equipped with vapor collection equipment that is compatible with the

terminal's vapor collection system.

40 CFR 60.502(f), Minn. R.

7011.1550

EQUI 20

(EU002) 8

Operation Requirement: The Permittee shall act to assure that the terminal's and the tank truck's vapor

collection systems are connected during each loading of a gasoline tank truck at the affected facility. This

includes training drivers in the hookup procedures and posting visible reminder signs at the affected

loading racks.

40 CFR 60.502(g), Minn. R.

7011.1550

EQUI 20

(EU002) 9

Operation Requirement: At all times, including periods of startup, shutdown, and malfunction, owners

and operators shall maintain and operate any affected facility including associated air pollution control

equipment in a matter consistent with good air pollution control practice for minimizing emissions.

Determination of whether acceptable operating and maintenance procedures are being used will be

based on information which may include, but is not limited to, monitoring results, opacity observations,

review of operating and maintenance procedures, and inspection.

40 CFR 60.11(d), Minn. R.

7017.2015

EQUI 20

(EU002) 10

Operation and Maintenance (O & M) Plan: The Permittee shall operate and maintain the VCU in

accordance with the facility O & M Plan and the control equipment manufacturer's specifications. The

Permittee shall keep copies of the O & M Plan available onsite for use by staff and MPCA staff.

40 CFR 64.8, Minn. R.

7007.0800, subp. 14, Minn. R.

7017.0200

EQUI 20

(EU002) 11

Monthly Inspections: Each calendar month, the vapor collection system, the vapor processing system, and

each loading rack handling gasoline shall be inspected during the loading of gasoline tank trucks for total

organic compounds liquid or vapor leaks. For purposes of this requirement, detection methods

incorporating sight, sound, or smell are acceptable.

40 CFR 60.502(j), 40 CFR 64.7,

Minn. R. 7011.1550, Minn. R.

7017.0200

EQUI 20

(EU002) 13

Semiannual Inspection: The Permittee shall inspect the VCU at least semiannual and shall maintain a

written record of the inspection and any action resulting from the inspection.

40 CFR 64.3(b)(4), Minn. R.

7007.0800, subp. 14, Minn. R.

7007.0800, subps. 4‐5, Minn. R.

7017.0200

EQUI 20

(EU002) 14

Total Organic Compounds : The Permittee shall conduct a performance test : Due before 09/07/2022

every 60 months to verify the emission factor of total organic compounds (mg/l) and pressure according

to 40 CFR 60.502(h). All subsequent tests are due by the end of each 60‐month period following that date.

Compliance with 40 CFR 60.502(b) shall be determined by complying with 40 CFR 60.503(b)‐(c) and 40 CFR

63.11092(a)(1)(i), and compliance with 40 CFR 60.502(h) shall be determined by complying with 40 CFR

60.503(d). Performance tests required under this condition were completed on November 18, 2002,

September 7, 2007, and August 21, 2012. The performance test shall be conducted at worst case

conditions as defined at Minn. R. 7017.2025, subp. 2, using EPA Reference Method 25A or 25B, or other

method approved by MPCA in the performance test plan approval.

Testing conducted during the 60 days prior to the performance test due date satisfies the performance

test due date, and will not reset the test due date for future tes ng as required:

1. by this permit;

2. by the most recently approved Performance Test Frequency Plan; or

3. within a No ce of Compliance le er.

Testing conducted more than two months prior to the performance test due date satisfies this test due

date requirement and will reset the performance test due date.

40 CFR 60.503(a), 40 CFR

60.8(a), 40 CFR 64.3(c), Minn. R.

7011.1550, Minn. R. 7017.0200,

Minn. R. 7017.2015, Minn. R.

7017.2020, subp. 1

EQUI 20

(EU002) 15

Leak Repairs: Each detection of a leak shall be recorded and the source of the leak repaired within 15

calendar days after it is detected.

40 CFR 60.502(j), 40 CFR 64.7,

Minn. R. 7011.1550, Minn. R.

7017.0200


EQUI 20

(EU002) 16

Corrective Actions: If the gauge pressure in the delivery tank exceeds 4,500 pascals (450 mm of water)

during product loading, the Permittee shall take corrective action as soon as possible according to the

control equipment manufacturer's specifications and the facility operation and maintenance plan. The

Permittee shall keep a log of all corrective actions taken with records entered upon completion of each

corrective action.

40 CFR 64.7(d)(1), Minn. R.

7017.0200

EQUI 20

(EU002) 17

Recordkeeping: The documentation file for each gasoline tank truck shall be updated at least once per

year to reflect current test results as determined by Method 27 or equivalent method approved by MPCA.

Trucks tested in accordance with 40 CFR Section 63.425(e) are considered to meet this requirement. This

documenta on shall include, as a minimum, the following informa on:

1. Test title: Gasoline Delivery Tank Pressure Test ‐EPA Reference Method 27 (or equivalent approved by

MPCA).

2. Tank owner and address.

3. Tank iden fica on number.

4. Tes ng loca on.

5. Date of test.

6. Tester name and signature.

7. Witnessing inspector, if any: Name, signature, and affilia on.

8. Test results: Actual pressure change in 5 minutes, mm of water (average for 2 runs).

40 CFR 60.505(b), Minn. R.

7011.1550

EQUI 20

(EU002) 18

Recordkeeping: The tank truck vapor tightness documentation required under 40 CFR 60.502(e)(1) shall be

kept on file at the terminal in a permanent form available for inspection.

40 CFR 60.505(a), Minn. R.

7011.1550

EQUI 20

(EU002) 19

Inspection Recordkeeping: A record of each monthly leak inspection required under 40 CFR 60.502(j) shall

be kept on file at the terminal for at least five (5) years and shall include, at a minimum, the following

informa on:

1. Date of inspec on.

2. Findings (may indicate no leaks discovered; or loca on, nature, and severity of each leak).

3. Leak determina on method.

4. Correc ve ac on (date each leak repaired, reasons for any repair interval >15 days).

5. Inspector name and signature.

40 CFR 60.505(c), Minn. R.

7007.0800, subp. 5, Minn. R.

7011.1550

EQUI 20

(EU002) 20

Recordkeeping of Notifications: The Permittee shall keep documentation of all notifications required

under 40 CFR Section 60.502(e)(4) on file at the terminal for at least five (5) years.

40 CFR 60.505(d), Minn. R.

7011.1550

EQUI 20

(EU002) 21

Component Recordkeeping: The Permittee shall keep records of all replacements or additions of

components performed on an existing vapor processing system on site for at least five (5) years.

40 CFR 60.505(f), Minn. R.

7011.1550

EQUI 20

(EU002) 22

Recordkeeping: The Permittee shall maintain records of the occurrence and duration of each startup,

shutdown, or malfunction of the VCU.

40 CFR 60.7(b), Minn. R.

7019.0100, subp. 1

EQUI 20

(EU002) 29

Performance Test No fica ons and Submi als;

Performance Test No fica on (wri en): due 30 days before each Performance Test,

Performance Test Plan: due 30 days before each Performance Test,

Performance Test Pre‐Test Mee ng: due 7 day before each Performance Test,

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

Performance Test Report ‐ Microfiche Copy or CD: due 105 day after each Performance Test.

Minn. R. 7017.2030, Minn. R.

7017.2035, subp. 1, Minn. R.

7017.2035, subp. 2

EQUI 20

(EU002) 30

Corrective Actions Reporting: All situations warranting corrective actions are deviations, the Permittee

shall report the deviations in the semiannual deviations report as required in the total facility section of

this permit.

40 CFR 64.9(a)(2)(i), Minn. R.

7017.0200

EQUI 38

(TK020) 1

Equip the storage vessels with a fixed roof with an internal floating type cover equipped with a continuous

closure device between the tank wall and the cover edge. The cover is to be floating at all times (i.e., off

the leg supports) except during initial fill and when the tank is completely emptied and subsequently

refilled. The process of emptying and refilling when the cover is resting on the leg supports shall be

continuous and shall be accomplished as rapidly as possible. Each opening in the cover except for

automatic bleeder vents and the rim space vents is to provide a projection below the liquid surface. Each

opening in the cover except for automatic bleeder vents, rim space vents, stub drains and leg sleeves is to

be equipped with a cover, seal, or lid which is to be maintained in a closed position at all times (i.e., no

visible gap) except when the device is in actual use. Automatic bleeder vents are to be closed at all times

when the cover is floating except when the cover is being floated off or is being landed on the leg

supports. Rim vents are to be set to open only when the cover is being floated off the leg supports or at

the manufacturer's recommended setting.

40 CFR 60.112a(a)(2), Minn. R.

7011.1520(B)

EQUI 38

(TK020) 2

At all times, including periods of startup, shutdown, and malfunction, the permittee shall, to the extent

practicable, maintain and operate EQUI 38, including associated air pollution control equipment, in a

manner consistent with good air pollution control practice for minimizing emissions. Determination of

whether acceptable operating and maintenance procedures are being used will be based on information

which may include, but is not limited to, monitoring results, review of operating and maintenance

procedures, and inspection of the source.

40 CFR 60.11(d), Minn. R.

7017.2015

EQUI 38

(TK020) 3

Maintain a record of the petroleum liquid stored, the period of storage, and the maximum true vapor

pressure of that liquid during the respective storage period.

40 CFR 60.115a(a), Minn. R.

7011.1520(B)


EQUI 38

(TK020) 4

Maintain a file of each type of petroleum liquid stored, of the typical Reid vapor pressure of each type of

petroleum liquid stored, of the dates of storage and withdrawals, and of the date on which the storage

vessel is empty. Determine and record by the 15th of the month for the previous month the average

monthly storage temperature and true vapor pressure of the petroleum liquid stored at such temperature

if the petroleum liquid has a true vapor pressure, as stored, greater than 470 mm Hg (9.1 psia).

This is a state only requirement and is not enforceable by the EPA Administrator and citizens under the

Clean Air Act. Minn. R. 7011.1510, subp. 1

EQUI 38

(TK020) 5

Recordkeeping: The Permittee shall maintain records of the occurrence and duration of any startup,

shutdown, or malfunction in the operation of the facility including; 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 38

(TK020) 6

Recordkeeping: The Permittee shall maintain a file of all measurements, maintenance, reports and records

for at least five years. This requirement is more stringent than 40 CFR Section 60.7(f), which specifies two

years.

40 CFR 60.7(f), Minn. R.

7007.0800, subp. 5(C), Minn. R.

7019.0100, subp. 1

EQUI 38

(TK020) 7

Available data on the typical Reid vapor pressure and the maximum expected storage temperature of the

stored product may be used to determine the maximum true vapor pressure from nomographs contained

in API Bulletin 2517, unless the Administrator specifically requests that the liquid be sampled, the actual

storage temperature determined, and the Reid vapor pressure determined from the sample(s).

40 CFR 60.115a(b), Minn. R.

7011.1520(B)

EQUI 38

(TK020) 8

The true vapor pressure of each type of crude oil with a Reid vapor pressure less than 13.8 kPa (2.0 psia)

or whose physical properties preclude determination by the recommended method is to be determined

from available data and recorded if the estimated true vapor pressure is greater than 6.9 kPa (1.0 psia).

40 CFR 60.115a(c), Minn. R.

7011.1520(B)

EQUI 38

(TK020) 9

The average monthly storage temperature is an arithmetic average calculated for each calendar month, or

portion thereof if storage is for less than a month, from bulk liquid storage temperatures determined at

least once every seven days.



EQUI 38

(TK020) 10

The true vapor pressure shall be determined by the procedure in American Petroleum Institute Bulletin

2517. This procedure is dependent upon determination of the storage temperature and the Reid vapor

pressure, which requires sampling of the petroleum liquids in the storage vessels. Unless the agency or

the commissioner requires in specific cases that the stored petroleum liquid be sampled, the true vapor

pressure may be determined by using the average monthly storage temperature and the typical Reid

vapor pressure. For those liquids for which certified specifications limiting the Reid vapor pressure exist,

that Reid vapor pressure may be used. For other liquids, supporting analytical data must be made

available on request of the agency or the commissioner when typical Reid vapor pressure is used.



EQUI 38

(TK020) 11

The following are exempt from the requirements of 40 CFR Sec on 60.115a:

1. Each owner or operator of each storage vessel storing a petroleum liquid with a Reid vapor pressure of

less than 6.9 kPa (1.0 psia) provided the maximum true vapor pressure does not exceed 6.9 kPa (1.0 psia).

2. The owner or operator of each storage vessel equipped with a vapor recovery and return or disposal

system in accordance with the requirements of 40 CFR Section 60.112a(a)(3) and (b), or a closed vent

system and control device meeting the specifications of 40 CFR Section 65.42(b)(4), (b)(5), or (c).

40 CFR 60.115a(d)(1)‐(2), Minn.

R. 7011.1520(B)

EQUI 38

(TK020) 12

No owner or operator shall build, erect, install, or use any article, machine, equipment or process, the use

of which conceals an emission which would otherwise constitute a violation of an applicable standard.

40 CFR 60.12, Minn. R.

7011.0050

EQUI 38

(TK020) 13

The Permittee shall submit a notification of any physical or operational change which increases emission

rate: due 60 days (or as soon as practical) before the change is commenced.

40 CFR 60.7(a)(4), Minn. R.

7019.0100, subp. 1


EQUI 40

(TK027) 1













40 CFR 60.112a(a)(2), Minn. R.

7011.1520(B)

EQUI 40

(TK027) 2







40 CFR 60.11(d), Minn. R.

7017.2015

EQUI 40

(TK027) 3



40 CFR 60.115a(a), Minn. R.

7011.1520(B)

EQUI 40

(TK027) 4








EQUI 40

(TK027) 5




inoperative.

40 CFR 60.7(b), Minn. R.

7019.0100, subp. 1

EQUI 40

(TK027) 6



years.

40 CFR 60.7(f), Minn. R.

7007.0800, subp. 5(C), Minn. R.

7019.0100, subp. 1

EQUI 40

(TK027) 7





40 CFR 60.115a(b), Minn. R.

7011.1520(B)

EQUI 40

(TK027) 8




40 CFR 60.115a(c), Minn. R.

7011.1520(B)

EQUI 40

(TK027) 9






EQUI 40

(TK027) 10












EQUI 40

(TK027) 11







40 CFR 60.115a(d)(1)‐(2), Minn.

R. 7011.1520(B)

EQUI 40

(TK027) 12



40 CFR 60.12, Minn. R.

7011.0050

EQUI 40

(TK027) 13



40 CFR 60.7(a)(4), Minn. R.

7019.0100, subp. 1

EQUI 69

(TK019) 1













40 CFR 60.112a(a)(2), Minn. R.

7011.1520(B)

EQUI 69

(TK019) 2







40 CFR 60.11(d), Minn. R.

7017.2015

EQUI 69

(TK019) 3



40 CFR 60.115a(a), Minn. R.

7011.1520(B)

EQUI 69

(TK019) 4








EQUI 69

(TK019) 5




inoperative.

40 CFR 60.7(b), Minn. R.

7019.0100, subp. 1

EQUI 69

(TK019) 6



years.

40 CFR 60.7(f), Minn. R.

7007.0800, subp. 5(C), Minn. R.

7019.0100, subp. 1

EQUI 69

(TK019) 7





40 CFR 60.115a(b), Minn. R.

7011.1520(B)

EQUI 69

(TK019) 8




40 CFR 60.115a(c), Minn. R.

7011.1520(B)

EQUI 69

(TK019) 9







EQUI 69

(TK019) 10











EQUI 69

(TK019) 11







40 CFR 60.115a(d)(1)‐(2), Minn.

R. 7011.1520(B)

EQUI 69

(TK019) 12



40 CFR 60.12, Minn. R.

7011.0050

EQUI 69

(TK019) 13



40 CFR 60.7(a)(4), Minn. R.

7019.0100, subp. 1

EQUI 77

(TK029) 1













40 CFR 60.112a(a)(2), Minn. R.

7011.1520(B)

EQUI 77

(TK029) 2







40 CFR 60.11(d), Minn. R.

7017.2015

EQUI 77

(TK029) 3



40 CFR 60.115a(a), Minn. R.

7011.1520(B)

EQUI 77

(TK029) 4








EQUI 77

(TK029) 5




inoperative.

40 CFR 60.7(b), Minn. R.

7019.0100, subp. 1

EQUI 77

(TK029) 6



years.

40 CFR 60.7(f), Minn. R.

7007.0800, subp. 5(C), Minn. R.

7019.0100, subp. 1


EQUI 77

(TK029) 7





40 CFR 60.115a(b), Minn. R.

7011.1520(B)

EQUI 77

(TK029) 8




40 CFR 60.115a(c), Minn. R.

7011.1520(B)

EQUI 77

(TK029) 9






EQUI 77

(TK029) 10











EQUI 77

(TK029) 11







40 CFR 60.115a(d)(1)‐(2), Minn.

R. 7011.1520(B)

EQUI 77

(TK029) 12



40 CFR 60.12, Minn. R.

7011.0050

EQUI 77

(TK029) 13



40 CFR 60.7(a)(4), Minn. R.

7019.0100, subp. 1

EQUI 80

(TK032) 1













40 CFR 60.112a(a)(2), Minn. R.

7011.1520(B)

EQUI 80

(TK032) 2







40 CFR 60.11(d), Minn. R.

7017.2015

EQUI 80

(TK032) 3



40 CFR 60.115a(a), Minn. R.

7011.1520(B)


EQUI 80

(TK032) 4








EQUI 80

(TK032) 5




inoperative.

40 CFR 60.7(b), Minn. R.

7019.0100, subp. 1

EQUI 80

(TK032) 6



years.

40 CFR 60.7(f), Minn. R.

7007.0800, subp. 5(C), Minn. R.

7019.0100, subp. 1

EQUI 80

(TK032) 7





40 CFR 60.115a(b), Minn. R.

7011.1520(B)

EQUI 80

(TK032) 8




40 CFR 60.115a(c), Minn. R.

7011.1520(B)

EQUI 80

(TK032) 9






EQUI 80

(TK032) 10











EQUI 80

(TK032) 11







40 CFR 60.115a(d)(1)‐(2), Minn.

R. 7011.1520(B)

EQUI 80

(TK032) 12



40 CFR 60.12, Minn. R.

7011.0050

EQUI 80

(TK032) 13



40 CFR 60.7(a)(4), Minn. R.

7019.0100, subp. 1

TREA 6

(CE001) 11

Operating Scenario 1: The Vapor Combustion Unit (VCU) shall be operated with the assist air blower on,

the MOV (vapor valve) open, and a pilot flame present at all times when emissions may be vented to TREA

6. If emissions vent to TREA 6 when any of the above conditions are not occurring, it shall be considered

an excursion as defined by 40 CFR pt. 64.1.

40 CFR 64.3(a)(2), Minn. R.

7007.0800, subp. 11, Minn. R.

7007.0800, subps. 4‐5, Minn. R.

7017.0200, Title I Condition:

Avoid major modification under

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

R. 7007.3000


TREA 6

(CE001) 12

Operating Scenario 2: The VCU shall be operated with the MOV (vapor valve) in the closed position as

demonstrated by the indicator on the unit when no emissions are venting to TREA 6. If the MOV is in an

open position when emissions are not venting to TREA 6, it shall be considered an excursion as defined by

40 CFR pt. 64.1.

40 CFR 64.3(a)(2), Minn. R.

7007.0800, subp. 11, Minn. R.

7007.0800, subps. 4‐5, Minn. R.



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

R. 7007.3000

TREA 6

(CE001) 13

The Permittee shall vent emissions from EQUI 19 to a VCU that meets the requirements of TREA 6

whenever EQUI 19 operates, and operate and maintain TREA 6 at all times that any emissions are vented

to TREA 6. The Permittee shall document periods of non‐operation of the control equipment TREA 6

whenever EQUI 19 is operating.

Title I Condition: Avoid major

modification under 40 CFR

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

7007.3000

TREA 6

(CE001) 20

The Permittee shall operate and maintain the VCU in accordance with the Operation and Maintenance (O

& M) Plan. The Permittee shall keep copies of the O & M Plan available onsite for use by staff and MPCA

staff.

40 CFR 64.8, Minn. R.

7007.0800, subp. 14, Minn. R.

7017.0200

TREA 6

(CE001) 21

Monitoring Equipment: The Permittee shall install and maintain a thermocouple or equivalent device on

TREA 6 to detect the presence of a flame as required by this permit. The monitoring equipment must be

installed, in use, and properly maintained whenever operation of the monitored control equipment is

required. This includes, but is not limited to, maintaining necessary parts for routine repairs.

40 CFR 64.7(b), Minn. R.

7007.0800, subp. 14, Minn. R.

7007.0800, subp. 4, Minn. R.

7017.0200

TREA 6

(CE001) 23

Daily Monitoring: At least once during every 24‐hour period the Permittee shall verify that control and

monitoring equipment is operating properly. For Operating Scenario 1, the Permittee shall verify that all

three operating conditions are being met; for Operating Scenario 2, the Permittee shall verify that the

MOV indicator shows that it is closed. The Permittee shall maintain a written record of the daily

verifications.

40 CFR 64.3(c), Minn. R.



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

R. 7007.3000

TREA 6

(CE001) 17610

Recordkeeping of daily monitoring: At least once during every 24‐hour period the Permittee shall record

the following:

1. The time, date, and results of the daily verification,

2. The applicable Operating Scenario (whether or not emissions are being vented to the VCU), and

3. Whether or not there was an excursion for the Operating Scenario.

40 CFR 64.3(b)(4), Minn. R.

7007.0800, subps. 4‐5, Minn. R.



40 CFR 52.51(b)(1)(i) and Minn.

R. 7007.3000

TREA 6

(CE001) 17615

Semi‐Annual Inspections: At least once per calendar half‐year, the Permittee shall inspect all of the control

equipment internal and external system components, including but not limited to the automated alarm or

shutdown system and the electrical systems. Inspections shall be separated by at least 120 days. The

Permittee shall maintain a written record of the inspection and any action resulting from the inspection.

40 CFR 64.3, Minn. R.

7007.0800, subps. 4‐5, Minn. R.

7017.0200

TREA 6

(CE001) 18740

Annual Calibration: The Permittee shall calibrate or replace the thermocouple at least once every 12

months and shall maintain a written record of the calibration and any action resulting from the calibration

or replacement.

40 CFR 64.3, Minn. R.

7007.0800, subp. 14, Minn. R.

7007.0800, subp. 5, Minn. R.

7017.0200

TREA 6

(CE001) 18760

Continued operation: Except for monitoring malfunctions, associated repairs, and required quality

assurance or control activities, the Permittee shall conduct all monitoring in continuous operation (or shall

collect data at all required intervals) at all times that the pollutant‐specific emissions unit is operating.

Data recorded during monitoring malfunctions, associated repairs, and required quality assurance or

control activities shall not be used for purposes of this part, including data averages and calculations, or

fulfilling a minimum data availability requirement, if applicable. A monitoring malfunction is any sudden,

infrequent, not reasonably preventable failure of the monitoring to provide valid data. Monitoring failures

that are caused in part by poor maintenance or careless operation are not malfunctions.

40 CFR 64.7(c), Minn. R.

7017.0200

TREA 6

(CE001) 18770

Corrective Actions: the Permittee shall take corrective action as soon as possible if any of the following

occur:

1. The air assist blower is not on during loading opera ons,

2. The presence of a flame is not detected during loading opera ons,

3. The MOV is open when no emissions are being vented to it, or

4. The VCU or any of its components are found to need repair during the inspec ons.

Corrective actions shall turn on the air assist blower, return the flame presence, close the MOV, and/or

include completion of necessary repairs identified during the inspection, as applicable. Corrective actions

include, but are not limited to, those outlined in the O & M Plan for the VCU. The Permittee shall keep a

record of the type and date of any corrective action taken, whether it was taken in a timely manner, and

an estimate of the amount of fuel loaded during the period of malfunction.

40 CFR 64.7(d), Minn. R.

7007.0800, subp. 14, Minn. R.

7007.0800, subp. 5, Minn. R.

7017.0200


TREA 6

(CE001) 18780

Response to excursions: Upon detecting an excursion, the Permittee shall restore operation of the VCU to

its normal or usual manner of operation as expeditiously as practicable in accordance with good air

pollution control practices for minimizing emissions. The response shall include minimizing the period of

any startup, shutdown or malfunction and taking any necessary corrective actions to restore normal

operation and prevent the likely recurrence of the cause of an excursion. Such actions may include initial

inspection and evaluation, recording that operations returned to normal without operator action, or any

necessary follow‐up actions to return operation to within the designated condition, or below the

applicable emission limitation or standard, as applicable.

40 CFR 64.7(d)(1), Minn. R.

7007.0800, subp. 14, Minn. R.

7017.0200

TREA 6

(CE001) 18800

Determination of whether the Permittee has used acceptable procedures in response to an excursion or

exceedance will be based on information available, which may include but is not limited to, monitoring

results, review of operation and maintenance procedures and records, and inspection of the control

device, associated capture system, and the process.

40 CFR 64.7(d)(2), Minn. R.

7007.0800, subp. 14, Minn. R.

7017.0200

TREA 6

(CE001) 18810

Recordkeeping Requirement: The Permittee shall maintain written records of the presence of the flame;

days of start up and shutdown of the VCU; any malfunction of and related corrective actions for the VCU;

performance tests; calibration checks; adjustments and maintenance; inspections; and all other

information in permanent form, suitable for inspection for at least five years following the date of such

measurements, maintenance, and records.

40 CFR 60.7(b), 40 CFR 64.9(b),

Minn. R. 7017.0200, Minn. R.

7019.0100, subp. 1

TREA 6

(CE001) 18830

The Permittee shall maintain records of monitoring data, monitor performance data, corrective actions

taken, and other supporting information required to be maintained. The Permittee may maintain records

on alternative media, such as microfilm, computer files, magnetic tape disks, or microfiche, provided that

the use of such alternative media allows for expeditious inspection and review, and does not conflict with

other applicable recordkeeping requirements.

40 CFR 64.9(b), Minn. R.

7017.0200

TREA 6

(CE001) 18840

As required by 40 CFR Section 64.9(a)(2), for the Semi‐Annual Deviations Report required by this permit

and/or the Notification of Deviations Endangering Human Health and the Environment required by this

permit, as applicable, the Permittee shall include the following related to the monitoring identified as

required by 40 CFR pt. 64: 1) Summary information on the number, duration, and cause of excursions or

exceedances, as applicable, and the corrective action taken; and 2) Summary information on the number,

duration, and cause for monitor downtime incidents.

40 CFR 64.9(a)(2), Minn. R.

7017.0200

TREA 6

(CE001) 18900

Documentation of Need for Improved Monitoring: If the Permittee fails to achieve compliance with an

emission limitation or standard for which the monitoring did not provide an indication of an excursion or

exceedance while providing valid data, or the results of compliance or performance testing document a

need to modify the existing pressure drop range, the Permittee shall promptly notify the MPCA and, if

necessary, submit a permit amendment application to address the necessary monitoring change.

40 CFR 64.7(e), Minn. R.

7017.0200

TREA 6

(CE001) 18901

If the Permittee replaces TREA 6, the replacement control must meet or exceed the control efficiency

requirements of TREA 6 as well as comply with all other requirements of TREA 6. Prior to making such a

change, the Permi ee shall apply for and obtain the appropriate permit amendment, as applicable.

If no amendment is needed for the replacement, the Permittee shall submit an electronic notice to the

Agency using Form CR‐05. The notice must be received by the Agency seven working days prior to the

commencement/start of replacement.



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

7007.3000

TREA 6

(CE001) 18902

Quality Improvement Plan (QIP): Based on the results of a determination made under 40 CFR 64.7(d)(2),

the Commissioner may require the Permittee to develop and implement a QIP in accordance with 40 CFR

64.8(b).

40 CFR 64.8(a), Minn. R.

7017.0200

TREA 7

(CE002) 11

Operating Scenario 1: The Vapor Combustion Unit (VCU) shall be operated with the assist air blower on,

the MOV (vapor valve) open, and a pilot flame present at all times when emissions may be vented to TREA

7. If emissions vent to TREA 7 when any of the above conditions are not occurring, it shall be considered

an excursion as defined by 40 CFR pt. 64.1.

40 CFR 64.3(a)(2), Minn. R.

7007.0800, subp. 11, Minn. R.

7007.0800, subps. 4‐5, Minn. R.



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

R. 7007.3000

TREA 7

(CE002) 12

Operating Scenario 2: The VCU shall be operated with the MOV (vapor valve) in the closed position as

demonstrated by the indicator on the unit when no emissions are venting to TREA 7. If the MOV is in an

open position when emissions are not venting to TREA 7, it shall be considered an excursion as defined by

40 CFR pt. 64.1.

40 CFR 64.3(a)(2), Minn. R.

7007.0800, subp. 11, Minn. R.

7007.0800, subps. 4‐5, Minn. R.



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

R. 7007.3000


TREA 7

(CE002) 13

The Permittee shall vent emissions from EQUI 20 to a VCU that meets the requirements of TREA 7

whenever EQUI 20 operates, and operate and maintain TREA 7 at all times that any emissions are vented

to TREA 7. The Permittee shall document periods of non‐operation of the control equipment TREA 7

whenever EQUI 20 is operating.



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

7007.3000

TREA 7

(CE002) 20

The Permittee shall operate and maintain the VCU in accordance with the Operation and Maintenance (O

& M) Plan. The Permittee shall keep copies of the O & M Plan available onsite for use by staff and MPCA

staff.

40 CFR 64.8, Minn. R.

7007.0800, subp. 14, Minn. R.

7017.0200

TREA 7

(CE002) 21

Monitoring Equipment: The Permittee shall install and maintain a thermocouple or equivalent device on

TREA 7 to detect the presence of a flame as required by this permit. The monitoring equipment must be

installed, in use, and properly maintained whenever operation of the monitored control equipment is

required. This includes, but is not limited to, maintaining necessary parts for routine repairs.

40 CFR 64.7(b), Minn. R.

7007.0800, subp. 14, Minn. R.

7007.0800, subp. 4, Minn. R.

7017.0200

TREA 7

(CE002) 23

Daily Monitoring: At least once during every 24‐hour period the Permittee shall verify that control and

monitoring equipment is operating properly. For Operating Scenario 1, the Permittee shall verify that all

three operating conditions are being met; for Operating Scenario 2, the Permittee shall verify that the

MOV indicator shows that it is closed. The Permittee shall maintain a written record of the daily

verifications.

40 CFR 64.3(c), Minn. R.



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

R. 7007.3000

TREA 7

(CE002) 17610

Recordkeeping of daily monitoring: At least once during every 24‐hour period the Permittee shall record

the following:

1. The time, date, and results of the daily verification,

2. The applicable Operating Scenario (whether or not emissions are being vented to the VCU), and

3. Whether or not there was an excursion for the Operating Scenario.

40 CFR 64.3(b)(4), Minn. R.

7007.0800, subps. 4‐5, Minn. R.



40 CFR 52.51(b)(1)(i) and Minn.

R. 7007.3000

TREA 7

(CE002) 17615

Semi‐Annual Inspections: At least once per calendar half‐year, the Permittee shall inspect all of the control

equipment internal and external system components, including but not limited to the automated alarm or

shutdown system and the electrical systems. Inspections shall be separated by at least 120 days. The

Permittee shall maintain a written record of the inspection and any action resulting from the inspection.

40 CFR 64.3, Minn. R.

7007.0800, subps. 4‐5, Minn. R.

7017.0200

TREA 7

(CE002) 18740

Annual Calibration: The Permittee shall calibrate or replace the thermocouple at least once every 12

months and shall maintain a written record of the calibration and any action resulting from the calibration

or replacement.

40 CFR 64.3, Minn. R.

7007.0800, subp. 14, Minn. R.

7007.0800, subp. 5, Minn. R.

7017.0200

TREA 7

(CE002) 18760

Continued operation: Except for monitoring malfunctions, associated repairs, and required quality

assurance or control activities, the Permittee shall conduct all monitoring in continuous operation (or shall

collect data at all required intervals) at all times that the pollutant‐specific emissions unit is operating.

Data recorded during monitoring malfunctions, associated repairs, and required quality assurance or

control activities shall not be used for purposes of this part, including data averages and calculations, or

fulfilling a minimum data availability requirement, if applicable. A monitoring malfunction is any sudden,

infrequent, not reasonably preventable failure of the monitoring to provide valid data. Monitoring failures

that are caused in part by poor maintenance or careless operation are not malfunctions.

40 CFR 64.7(c), Minn. R.

7017.0200

TREA 7

(CE002) 18770

Corrective Actions: the Permittee shall take corrective action as soon as possible if any of the following

occur:

1. The air assist blower is not on during loading opera ons,

2. The presence of a flame is not detected during loading opera ons,

3. The MOV is open when no emissions are being vented to it, or

4. The VCU or any of its components are found to need repair during the inspec ons.

Corrective actions shall turn on the air assist blower, return the flame presence, close the MOV, and/or

include completion of necessary repairs identified during the inspection, as applicable. Corrective actions

include, but are not limited to, those outlined in the O & M Plan for the VCU. The Permittee shall keep a

record of the type and date of any corrective action taken, whether it was taken in a timely manner, and

an estimate of the amount of fuel loaded during the period of malfunction.

40 CFR 64.7(d), Minn. R.

7007.0800, subp. 14, Minn. R.

7007.0800, subp. 5, Minn. R.

7017.0200

TREA 7

(CE002) 18780

Response to excursions: Upon detecting an excursion, the Permittee shall restore operation of the VCU to

its normal or usual manner of operation as expeditiously as practicable in accordance with good air

pollution control practices for minimizing emissions. The response shall include minimizing the period of

any startup, shutdown or malfunction and taking any necessary corrective actions to restore normal

operation and prevent the likely recurrence of the cause of an excursion. Such actions may include initial

inspection and evaluation, recording that operations returned to normal without operator action, or any

necessary follow‐up actions to return operation to within the designated condition, or below the

applicable emission limitation or standard, as applicable.

40 CFR 64.7(d)(1), Minn. R.

7007.0800, subp. 14, Minn. R.

7017.0200


TREA 7

(CE002) 18800

Determination of whether the Permittee has used acceptable procedures in response to an excursion or

exceedance will be based on information available, which may include but is not limited to, monitoring

results, review of operation and maintenance procedures and records, and inspection of the control

device, associated capture system, and the process.

40 CFR 64.7(d)(2), Minn. R.

7007.0800, subp. 14, Minn. R.

7017.0200

TREA 7

(CE002) 18810

Recordkeeping Requirement: The Permittee shall maintain written records of the presence of the flame;

days of start up and shutdown of the VCU; any malfunction of and related corrective actions for the VCU;

performance tests; calibration checks; adjustments and maintenance; inspections; and all other

information in permanent form, suitable for inspection for at least five years following the date of such

measurements, maintenance, and records.

40 CFR 60.7(b), 40 CFR 64.9(b),

Minn. R. 7017.0200, Minn. R.

7019.0100, subp. 1

TREA 7

(CE002) 18830

The Permittee shall maintain records of monitoring data, monitor performance data, corrective actions

taken, and other supporting information required to be maintained. The Permittee may maintain records

on alternative media, such as microfilm, computer files, magnetic tape disks, or microfiche, provided that

the use of such alternative media allows for expeditious inspection and review, and does not conflict with

other applicable recordkeeping requirements.

40 CFR 64.9(b), Minn. R.

7017.0200

TREA 7

(CE002) 18840

As required by 40 CFR Section 64.9(a)(2), for the Semi‐Annual Deviations Report required by this permit

and/or the Notification of Deviations Endangering Human Health and the Environment required by this

permit, as applicable, the Permittee shall include the following related to the monitoring identified as

required by 40 CFR pt. 64: 1) Summary information on the number, duration, and cause of excursions or

exceedances, as applicable, and the corrective action taken; and 2) Summary information on the number,

duration, and cause for monitor downtime incidents.

40 CFR 64.9(a)(2), Minn. R.

7017.0200

TREA 7

(CE002) 18900

Documentation of Need for Improved Monitoring: If the Permittee fails to achieve compliance with an

emission limitation or standard for which the monitoring did not provide an indication of an excursion or

exceedance while providing valid data, or the results of compliance or performance testing document a

need to modify the existing pressure drop range, the Permittee shall promptly notify the MPCA and, if

necessary, submit a permit amendment application to address the necessary monitoring change.

40 CFR 64.7(e), Minn. R.

7017.0200

TREA 7

(CE002) 18901

If the Permittee replaces TREA 7, the replacement control must meet or exceed the control efficiency

requirements of TREA 7 as well as comply with all other requirements of TREA 7. Prior to making such a

change, the Permi ee shall apply for and obtain the appropriate permit amendment, as applicable.

If no amendment is needed for the replacement, the Permittee shall submit an electronic notice to the

Agency using Form CR‐05. The notice must be received by the Agency seven working days prior to the

commencement/start of replacement.



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

7007.3000

TREA 7

(CE002) 18902

Quality Improvement Plan (QIP): Based on the results of a determination made under 40 CFR 64.7(d)(2),

the Commissioner may require the Permittee to develop and implement a QIP in accordance with 40 CFR

64.8(b).

40 CFR 64.8(a), Minn. R.

7017.0200

ATTACHMENT 3:

Compliance Assurance Monitoring (CAM) Plan

COMPLIANCE ASSURANCE MONITORING PLAN

Vapor Combustion Unit for VOC Control: Magellan Pipeline Company, L.P. - St. Paul Terminal

1. Background a. Emissions Unit

Description: MPL Loading Rack, Flint Hills Resources (FHR) Loading Rack Identification: Stack Number 001, Stack Number 002 Stack Designation: Vapor Combustion Unit MPCA Facility Number: 12300070 Facility: Magellan Pipeline Company, L.P. - St. Paul Terminal

b. Applicable Regulation, Emission Limit and Monitoring Requirements Regulation No.: 40 CFR Part 60, Subpart XX Regulated Pollutant: Total Organic Compounds Emission Limit: 35 milligrams of TOC per liter of gasoline loaded Monitoring Requirements: Monthly inspection of vapor collection system, vapor processing system, and each loading rack managing gasoline for TOC liquid or vapor leaks. Detection methods incorporating sight, sound, or smell are acceptable.

Regulation No.: Permit Regulated Pollutant: Total Organic Compounds Emission Limit: 35 milligrams of TOC per liter of gasoline loaded Monitoring Requirements:

• Monthly inspection. • The Permittee shall conduct all necessary maintenance and make all

necessary attempts to keep all air pollution monitoring equipment in pro per operating condition at all times.

• Required submittal of an Operation and Maintenance Plan.

c. Control Technology: Vapor Combustion Unit

2. Monitoring Approach • The primary vapor combustion unit parameters to be included in the prop osed monitoring

approach are outlined in Table 1. • The parameters and ranges included in Table I are thos e recommended by the equipment

manufacturer. • The vapor combustion unit systems are continuously monitored for status and alarm

information at the loading rack controller. • The occurrence of any of the monitored alarms will cause the truck loading system to shut

down, allowing those transports which arc in the process of loading to finish, but not allow any additional loading until the alarm has been cleared.

• All routine maintenance, malfunctions, and unintended shutdowns of the vapor control system will be documented on the VCU Startup, Shutdown, Maintenance, and Malfunction Log.

• Maintenance shall be performed in a manner taking into consideration the manufacturer's recommendations.

• If any system component is found to be faulty during routine maintenance, it will be repaired in an exp editious manner. All repairs will be reported in the shutdown and maintenance report.

• Additional inspections will be conducted in accordance to the requirements of 40 CFR Part 60, Subpart XX.

3. Data Availability • Monitoring of the parameters will be done on a continual basis while the equipment is

operated. Due to the design of the monitoring and alarm system, the information is not recorded, only a no tification supplied by way of an alarm when an operational parameter is exceeded.

TABLE 1 - MONITORING APPROACH - MAGELLAN LOADING RACK VAPOR COlViBUSTION UNIT Indicator 1 indicator 2 Indicator 3 indicator 4 Indicator 5 indicator 6 Indicator 7 indicator 8

1 Indicator Liquid Seal Level Blower Failure First Stage Flame Arrester High Temp

Second Stage Flame Arrester High Temp

Pilot Gas Pressure Emergency Shutdown

Pilot Flame Fa&re

Power Failure

Measurement Approach

Float Breaker Thermocouple Thermocouple Pressure Gauge Float Fire Eyes Indicator to PLC

2. Indicator Range High and Low Level loss of coil on starter or motor failure

ISO cleg. F 160 deg.F High: above 10 psi Low: below 1.5 psi

High Condensate Tank Level

Mo Flame No Power

3. Performance Criteria

A. Data Representatives

The sensor supplies direct measurement of the liauid level.

Tha sensor supplies direct information on the blower operational status.

The sensor supplies direct information on the associated temperature.

The sans or supplies direct information on the associated temperature.

The sensor supplies direct measurement of pilot gas pressure.

The sensor supplies direct measurement of the liquid seal.

The sensor supplies direct information on the associated temperature.

The sensor supplies direct status of sower supply.

B. Verification of Operational Status Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

C. QA'QC Practices and

Criteria

VCU maintenance activities wifl be conducted on a semiannual basts, taking into account manufacturer's recommendations. Visual inspections will occur on a weekly basis.

VCU maintenance activities will be conducted on a semi-annual basis, taking into account manufacturer's recommendations. Visual inspections will occur on a weekly basis.

VCU maintenance activities wifl be conducted on a semiannual basis, taking into account manufacturer's recommendations. Visual inspections will occur on a weekly basis.

VCU maintenance activities will be conducted on a semi-annual basis, taking into account manufacturer's recommendations. Visual inspections wifl occur on a weekly basis.

VCU maintenance activities will be conducted on a semiannual basis, taking into account manufacturer's recommend at ion s. Visual inspections will occur on a weekly basis.

VCU maintenance activities will be conducted on a semi-annual basis, taking into account manufacturer's recommendations. Visual inspections will occur on a weekly basis.

VCU maintenance activities wtfl be conducted on a semi-annual basis, taking into account manufacturer's recommendation s. Visual inspections wii! occur on a weekly basis.

VCU maintenance activities will be conducted on a semi-annual basis, taking into account manufacturer's recommendation s. Visual inspections will occur on a weekly basis.

D. Monitoring Frequency Continuous Continuous Continuous Continuous Continuous Continuous Continuous Continuous

Data Collection Procedure

Alarm screen at loading rack controller.

Alarm screen at loading rack controller



Alarm screen at loading rack coniroitei.



Alarm screen at leading rack controller.

Average Period No average is taken. No average is

taken. No average is taken. No average 5$

taken. Mo average is taken. No average is

taken, No average >s taken.

No average is taken.

T

TABLE 1 • MONITORING APPROACH - FLINT HILLS RESOURCES (FUR) LOADiNG RACK VAPOR COMBUSTION UNIT indicator 1 lndica;or 2 Indicator 3 Indicator 4 Indicator 5 indicator 5 Indicator ? indicator 8

i. indicator Liquid Sea! Level Blower Failure First Stage Flame Arrester High Tenp

Second Stage Flame Arrester High Tern a

Pilot Gas Prassyrs emergency Shutdown

Pilot Flame Failure

Power Failure

ri/seasnreiwt Approach

Fin at Breaker Thermocouple Thermocouple Pressure Gauge rioat Flam© Rod indicator to PLC

2. indicator Range High ar.c Low level Loss Of coil on starter ormoEOr failure

160 (Jeg. F *50 iieg F High: above 10 psi Low: be tow 1.5 psi

Nigh Condensate Tank Level

No Flame No Power

3. Performance Criteria

A, Data Representatives

Trie sensor supplies direct measurement of the liquid level

The sensor supplies direct .reformation on the slower operatic-sal status

The sensor supplies direc: information on tha associated temperature.

The sensor supplies direct info in at ion on tiie associated temperature.

Ti'e sensor supplies direct measurement of pilot gas pressure.

The sensor supplies direct measurement c-t the liquid sea!.

The sensor supplies d red information on she associated •eroperatye.

Tie sensor supplies direct status of power supply.

B, Verification of Operational Status Net applicable Not applicable Not applicable Not applicable Not applicable Moi acotscable Not applicable Not applicable

C QA/QC Practices anc

criteria

VCU ma ntenarsce acivtsies will be conducted on a semiannual basis, taking into asceun: manufacturer's recommendations. Visual inspections win ocsuroo s weekly basis.

VCU maintenance activities will be conducted on a semi-annual oasis, taking into account manufacturer's recommendations, visual msp&3tlcr*s will occur on a weekly basis.

VCU maintenance activities will be conducted on a semiannual bas.s, taking into accourt manufacturer's recoiRmendasicns. vsual inspections will occur on a weekly basis.

VCU maintenance activities will be conducted on a semi-annual oasis, taking ;n1c account manufacturer's recommend stiofts. visual inspections will occur on a weekly basis.

VCU maintenance activities wil be conducted on a semiannual basis, taking into account manufacturer's recoro mentations. Visual inspections wi occur on a weekly basis.

VCU maintenance activities will be conducted on a semi-ennual basis, taking into account manufacturer's 'ecommendations. Visual inspections win occur on a weekly basis

VCU maintenance activities will be conducted on a semi-annual basis, takhg into account niarutscturer's recommend at) or s visual inspections will occur on a vae-dy basis.

vcu maintenance activities will be conducted on a semi-annual basis, taking into account manufacturer's recommendation s. Vsual inspections will CK-C-Uf o n a weekly basis.

D Monitoring Frequency Continuous Continuous Continuous Continuous Continuous Continuous Continuous Continuous

Data Collection Procedure

Alarm screen st loedsrtg tzcM c ontroller.

Alarm screen a: oading rack controller.

Alafra scresrt al loading rack controller.

Alarm screen at ioBcing rack controller.


Alarm screen at ioading rack contra ler.

Alarn screen at loading rack controller,

A'arm screen at loading rack controller.

Average Period Nr. average is taken. Mo average is

:aken.. No average is taken. Mo average is

taken. No average is taken. No average is

taken. No ave'age is taken.

No average is taken.

r

ATTACHMENT 4:

U.S. Environmental Protection Agency (EPA) Vapor Combustion Unit (VCU) Applicability Determination

U.S. Environmental Protection Agency Applicability Determination Index

Control Number: M020005

Category: MACT EPA Office: Region 1 Date: 06/18/2002 Title: Gasoline Vapor Combustion Unit Recipient: Douglas L. McVay Author: Michael P. Kenyon

Subparts: Part 63, R, Gasoline Distribution Facilities

References: 63.427

Abstract:

Q. Would EPA classify the John Zink Gasoline Vapor Combustion Unit as a thermal oxidization system or a flare?

A. In previous applicability determinations for similar units, EPA has determined that these types of units should be classified as thermal oxidation systems. Therefore, these units are subject to the temperature monitoring requirements of 40 CFR Section 63.427(a)(3). EPA had only intended for the flare monitoring requirements of 40 CFR Section 63.427(a)(4) to apply to open flame flares.

Letter:

June 18, 2002

Douglas L. McVay Associate Supervisor Engineering Office of Air Resources Rhode Island Department of Environmental Management 235 Promenade Street Providence, Rhode Island 02908-5767

Dear Mr. McVay:

The U.S. Environmental Protection Agency (EPA) has reviewed your letter dated April 25, 2002 regarding ExxonMobil's bulk gasoline terminal in East Providence, RI. ExxonMobil's bulk gasoline terminal is subject to 40 CFR Part 63 Subpart R, the national emission standard for hazardous air pollutants for gasoline distribution facilities. You requested a determination as to how EPA would classify the John Zink Gasoline Vapor Combustion Unit. This letter provides you with a written applicability determination.

In previous applicability determinations for similar units, EPA has determined that these types of units should be classified as thermal oxidation systems. Therefore, these units are subject to the temperature monitoring requirements of Section 63.427(a)(3). EPA had only intended for the flare monitoring requirements of Section 63.427(a)(4) to apply to open flame flares.

Although the facility is subject to the temperature monitoring requirements of Section 63.427(a)(3), the facility may apply for alternative monitoring under Section 63.8(4)(i). The facility should send any alternative monitoring requests to:

Denny Dart, Senior Enforcement Coordinator U.S. EPA New England One Congress Street Suite 1100 (CAP) Boston, MA 02114-2023

This applicability determination does not relieve ExxonMobil of responsibility for complying fully with any and all applicable federal, state and local laws, regulations and permits.

If you have any questions about this determination or need further assistance, please contact Susan Lancey of my staff at (617) 918-1656.

Sincerely,

Michael P. Kenyon, Chief Air Programs Branch

Documents

Technical Support Document for Draft Air Emission Permit ... - 12300070-101... · tank truck loading racks with vapor collection systems and vapor combustion units (VCUs), and insignificant