TECHNICAL SUPPORT DOCUMENT For DRAFT/PROPOSED AIR … · Great River Energy‐ Cambridge was subject to CAIR when initially promulgated in 2005. Great River Energy‐ Cambridge submitted

Technical Support Document, Permit Action Number: 05900014‐004 Page 1 of 14

TECHNICAL SUPPORT DOCUMENT

For DRAFT/PROPOSED AIR EMISSION PERMIT NO. 05900014‐004

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

Table 1. Applicant and Source Address

Applicant/Address Stationary Source/Address

(SIC Code: 4911)

Great River Energy 12300 Elm Creek Boulevard Maple Grove, MN 55369

Great River Energy ‐ Cambridge

2438 349th Avenue Northeast

Cambridge, Isanti County, Minnesota 55008

Contact: Greg Archer Phone: 763‐445‐5206

1.2 Facility Description Great River Energy owns and operates a simple‐cycle combustion turbine generating plant in Cambridge,

Isanti County, Minnesota. The facility consists of one 29.3 megawatts (MW) combustion turbine, a 190

MW natural gas turbine equipped with dry low NOx burners, a black‐start generator, emergency diesel

fire pump, telecom building generator, a fuel tank for distillate oil storage, associated fuel oil forwarding

system and insignificant activities.

The facility is a major source under the federal operation permits program (40 CFR pt. 70) and non major

source under federal New Source Review (NSR). The facility is an area source under the National

Emission Standards for Hazardous Air Pollutants (NESHAPs, 40 CFR pt. 63). This facility is subject to the

Acid Rain Program and was subject the Clean Air Interstate Rule (CAIR) but is now subject to the

Transport Rule (TR)/Cross‐State Air Pollution Rule (CSAPR).

1.3 Description of the Activities Allowed by this Permit Action This permit action is the reissuance of the Part 70 operating permit.


1.4 Description of Notifications and Applications Included in this Action

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

01/24/2013 4275 Part 70 Reissuance Application

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

21 21 5.1 140 245 122 312,570 14 1.9 2.7

Total Facility Actual

Emissions (2012)

0.302 0.301 0.050 0.311 32.9 14.7 * 1.05 *

*Not reported in MN emission inventory.

Table 4. Facility Classification Classification Major/Affected Source Synthetic Minor/Area Minor/Area

PSD X

Part 70 Permit Program X

Part 63 NESHAP 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.

PTE Calculations were updated to include Greenhouse Gases (GHGs), and PM2.5 emissions.

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

Appendix D was added to the permit. Appendix D contains the 40 CFR pt. 63, subp. ZZZZ requirements for emergency diesel fire pump engine (EU 003) and black start diesel engine (EU 004) since the facility is an area source.

Appendix E was added to the permit. Appendix E contains the 40 CFR pt. 63, subp. ZZZZ requirements for telecom building generator.

On November 3, 2009, EPA promulgated a final rule entitled “Administrative Stay of Clean Air Interstate Rule (CAIR) for Minnesota; Administrative Stay of Federal Implementation Plan to Reduce Interstate Transport of Fine Particulate Matter and Ozone for Minnesota” (74 FR 56721). This rule became effective on December 3, 2009. The rule states that EPA is staying the


application of CAIR and the CAIR FIP with respect to Minnesota and Minnesota sources, pending further rulemaking in response to the DC Circuit Court’s remand of CAIR to EPA. CAIR requirements were removed from the permit. The Cross‐State Air Pollution Rule (CSAPR) general requirements stating that the facility shall comply with 40 CFR pt. 97 have been added at the total facility level, as well as requirements stating that the facility shall submit information related to 40 CFR pt. 97 when requested by the MPCA after the sunset of CAIR.

Insignificant activities data have been updated based on the equipment that was actually installed.

Updated the Data Acquisition Systems (DAS) to reflect existing continuous emission monitoring systems (CEMS) MR 001 and MR 002 for NOx and O2 respectively, which were certified and installed in 2011.

MRs 003 and 004 were removed from the permit. EU 001 lists monitoring systems MR 003 and MR 004 to reflect a future ability to install CEMS. EU 001 does not currently have CEMS; therefore, MR 003 and MR 004 will be removed from the permit until the Permittee plans to install the units. EU 001 does have a calibrated fuel flow monitor, consistent with EPA 40 CFR Section 75.19, a Low Mass Emissions (LME) requirement, which was installed to comply with CAIR. QA/QC plan requirements were added under EU 001.

Based on EPA authorizations to use Part 75 in lieu of Part 60 for RATA/linearity schedules, the permit was updated to reflect this authorization.

NOx Predictive Emissions Monitoring System (PEMS) has been removed from the site; therefore all the applicable requirements under GP 002 were removed from the permit. The Permittee has no intention to replace with another PEMS.

Under GP 002, the citations to 40 CFR pt. 72, Section 2.2.2 were removed since these requirements apply to flow monitors. EU 002 does not have a flow monitor.

Low NOx burners (CE 001) for NOx control are listed for natural gas combustion turbine (EU 002). These burners are integral to the combustion process, are not considered control devices as defined in 40 CFR Section 64.1. (See also the definitions in NSPS, 40 CFR pt. 60, subp. KKKK for stationary turbine, which excludes emission controls, and lean premix stationary combustion turbine, which inherently include the premix burner, as a non‐emission control, which is consistent with 40 CFR Section 64.1.) Based on this information from the Permittee, CE 001 was removed from the facility description in Delta.

Fuel certification is no longer necessary for compliance with Minn. R. 7011.2300; therefore, the requirement was removed from EU 003 and EU 004. The fuel type restriction will meet the requirements of 40 CFR Section 80.510(c), of less than 15 parts per million (ppm).

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

2. Regulatory and/or Statutory Basis New Source Review The facility is an existing non major source under New Source Review regulations. No changes are authorized by this permit. Part 70 Permit Program The facility is a major source under the Part 70 permit program.


New Source Performance Standards (NSPS) EU 002 is subject to 40 CFR pt. 60, subp. KKKK, Standards of Performance for Stationary Combustion Turbines. In addition to the general requirements, the subpart contains limits for NOx and SO2 provisions to monitor sulfur and nitrogen content of fuels burned, and for CEMS. EU 002 is connected to Northern Natural Gas pipeline, which has a maximum sulfur content of less than 20 grains of sulfur or less per 100 standard cubic feet. By maintaining a current tariff sheet, as indicated in 40 CFR Section 60.4365(a), EU 002 is exempt from 40 CFR pt. 60, subp. KKKK sulfur monitoring and annual performance test requirements as described in 40 CFR Section 60.4365. EU 001 is not subject to 40 CFR pt. 60, subp. KKKK due to its construction date which was August 1, 1977. The subpart is applicable to units that commenced construction, modification or reconstruction after February 18, 2005. The provisions of 40 CFR pt. 60 subp. GG (Standards of Performance for Stationary Gas Turbines) are applicable to all stationary gas turbines, which commence construction, modification, or reconstruction after October 3, 1977, with a heat input at peak load equal to or greater than 10 mmBtu/hr, based on the lower heating value of the fuel fired. The combustion turbine (EU 001) was constructed on August 1, 1977 and has a peak load greater than 10 mmBtu/hr but the burners were replaced during permit action 002 which resulted in a decrease in hourly emission rates of pollutants regulated under the rule; therefore, 40 CFR pt. subp. GG does not apply to the combustion turbine (EU 001). EU 002 is exempt from the requirements of 40 CFR pt. 60, subp. GG because the turbine is regulated under 40 CFR pt. 60, subp. KKKK. The NOx limit of 103.8ppm by volume was removed because it was based on 40 CFR pt. 60, subp. GG. The engines (EUs 003 and 004) are not subject to 40 CFR pt. 60, subp. IIII, Standards of Performance for Stationary Compression Ignition Internal Combustion Engines based on the date they were constructed (ordered) and manufactured. National Emission Standards for Hazardous Air Pollutants (NESHAP) The existing facility is an area source for HAPs and is subject to 40 CFR pt. 63, subp. ZZZZ , the Reciprocating Internal Combustion Engines (RICE) for the three existing engines. Combustion turbines (EUs 001 and 002) are not subject to 40 CFR pt. 63 subp. YYYY, National Emission Standards for Hazardous Air Pollutants for Stationary Combustion Turbines because the turbines are not located at a major source of HAP emissions. Compliance Assurance Monitoring (CAM)

This permit action is a reissuance of a Part 70 permit; therefore, CAM applies to any emission units which meet the CAM applicability requirements in 40 CFR pt. 64:

The unit is subject to an emission limitation or standard for the applicable regulated air pollutant,

The unit uses a control device to achieve compliance, and

The unit has potential pre‐control device emissions of the pollutant that are equal to or greater than 100 percent of the amount, in tons per year, required for the source to be classified as a major source.


The facility does not use a control device to achieve compliance; therefore, the requirements of 40 CFR pt. 64 are not applicable. Acid Rain program The facility is an affected facility and the combustion turbine, EU 002 is subject to the acid rain provisions in 40 CFR pt. 75. The Phase II permit application is included in the permit as Appendix B. Clean Air Interstate Rule (CAIR) and the Transport Rule (TR)/Cross‐State Air Pollution Rule (CSAPR)

Great River Energy‐ Cambridge was subject to CAIR when initially promulgated in 2005.

Great River Energy‐ Cambridge submitted a CAIR application on June 30, 2008.

CAIR was administratively stayed in Minnesota in December of 2009, so the application was returned.

CAIR was replaced by TR/CSAPR in 2011, but TR/CSAPR was stayed by the D.C. Circuit, and EPA was told to go back to CAIR.

The Supreme Court reversed the decision in 2014, and requested the D.C. Circuit to lift the stay

The D.C. Circuit court did so, with an extension of the original compliance dates by three years

Now, implementation of CSAPR will occur. Additional EPA guidance is expected in early 2015.

For now, general requirements stating that the facility shall comply with 40 CFR pt. 97 have been added at the total facility level, as well as requirements stating that the facility shall submit information related to 40 CFR pt. 97 when requested by the MPCA.

When EPA guidance is available on how to incorporate CAIR requirements in permits, we plan on sending letters to CSAPR facilities. This letter may include a request for an amendment application. Therefore, a requirement making it clear that an amendment application must be submitted for newly promulgated applicable requirements if there are 3 years remaining in the permit term has also been added at the total facility level.

Minnesota State Rules

Minn. R. 7011.0715 Standards of Performance for Post‐1969 Industrial Process Equipment for Insignificant Activities

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

Table 5. Regulatory Overview of Facility Subject Item* Applicable Regulations Rationale

FC 40 CFR pt. 72 Subject to the U.S. EPA Acid Rain Program codified at 40 CFR pts. 72,

73, 75, 77 and 78.

FC Minn. R. 7030.0010 through 7030.0080

The language 'This is a state‐only requirement and is not enforceable

by the U.S. Environmental Protection Agency (EPA) Administrator

and citizens under the Clean Air Act' refers to permit requirements

that are established only under state law and are not established

under or required by the federal Clean Air Act. The language is to

clarify the distinction between permit conditions that are required

by federal law and those that are required only under state law.

State law‐only requirements are not enforceable by the EPA or by

citizens under the federal Clean Air Act, but are fully enforceable by

the MPCA and citizens under provisions of state law.


Subject Item* Applicable Regulations Rationale

GP 001 (NOx

limit)

40 CFR § 52.21 and Minn. R. 7007.3000

Title I Condition: limit taken to avoid major source status. This limit

includes a total NOX emission limit of 244 tons/yr. Since NOx is the

limiting pollutant, all other criteria pollutants would be less than 250

tons/yr.

EU 001

(Combustion

Turbine)

Minn. R. 7011.2300

40 CFR pt. 97

Standards of Performance for Stationary Internal Combustion

Engines. The rule applies to opacity and SO2.

Transport Rule (TR)/Cross‐State Air Pollution (CSAPR). The rule

applies to NOx and SO2.

EU 002

(Combustion

Turbine)

40 CFR pt. 60, subp. KKKK New Source Performance Standards for Stationary Gas Turbines. The

rule applies to NOx and SO2.

40 CFR pt. 72 The Acid Rain application is included as an appendix to the permit.

EUs 003 and

004 (Pump

Engine and

Black Start

Engine)

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

Engines. The rule applies to opacity and SO2.

40 CFR § 52.21 and Minn. R. 7007.3000

Title I Condition: limit on hours of operation set in a previous permit.

40 CFR pt. 63, subp. ZZZZ National Emission Standards for Hazardous Air Pollutants (NESHAP)

for Stationary Reciprocating Internal Combustion Engines. All engines

are Existing, Compression Ignition, emergency less than 500hp

Engines.

*Location of the requirement in the permit (e.g., EU, SV, GP, etc.). 3. Technical Information 3.1 Calculations of Potential to Emit Attachment 2 to this TSD contains Form GI‐07, which summarizes the PTE of the Facility, while Attachment 1 contains detailed spreadsheets and supporting information prepared by the Permittee and audited and approved by the MPCA staff. The PTE emissions for the PM, PM10,VOCs and HAPs for the turbines were based on emission factors from AP‐42 and EPA Technology Transfer Network Air Toxics Website, Stationary Combustion Turbines NESHAP, Combustion Turbine Emissions. PM2.5 PTE emissions were estimated based upon EPA’s Webfire emission factors. GRE’s Turbine manufacturer does not have PM2.5 emission estimates. The EPA test procedures (Method 5 and Method 202) have significant difficulties with the elevated temperatures of combustion turbine exhaust and the extremely low emissions. While CO is not directly limited through an emission limit, it is inherently limited by the NOX limit on GP 001 and the startup time limit of 45 minutes. CO emissions are significantly higher during the startup, when the dry low NOx combustors are not operating in lean pre‐mix mode. It was demonstrated for the permit of another Great River Energy facility with the same type of combustion gas turbine at the Great River Energy‐Pleasant Valley facility that based on startup and operating mode emission factors provided by the Permittee, and the relative amount of time that the combustion turbine generators would spend in “normal” operation vs.


“startup” operation, it is conservative to assume that overall CO emissions would be 50% of the NOX emissions. NOX emissions from EU 001 and EU 002 are measured using a NOX CEMS, as required by the NSPS and Acid Rain programs. The Permittee will follow the fuel sulfur monitoring requirements as indicated in 40 CFR Section 60.4365. CO2e includes CO2 emissions as well as CO2e emissions of CH4 and N2O calculated using Global‐warming potential (GWP). Emission Factors for CO2, CH4 and N2O taken from EPA 40 CFR pt. 98 Tables C‐1 and C‐2. EU 003 has a source restricted operation to 150 hours per year. The PM PTE emissions were calculated based on PM using emission factors supplied by the manufacturer. PM10 emissions were based on emission factors from AP‐42 Table 3.3‐1. The manufacturer does not supply an emission factor for PM2.5; therefore PM2.5 was conservatively assumed the same as PM10. CO2e includes CO2 emissions as well as CO2e emissions of CH4 and N2O calculated using GWP. Emission Factors for CO2, CH4 and N2O (lb/mmBtu) taken from EPA 40 CFR 98 Tables C‐1 and C‐2 as no other GHG emission factors are provided for this type of engine. The Permittee will follow the emergency only operating provisions of 40 CFR pt. 63, subp. ZZZZ. EU 004 has a source restricted operation to 70 hours per year. The PM and PM10 PTE emissions were based on emission factors from AP‐42 Table 3.3‐1. No emission factor for PM2.5 is provided in AP‐42 or EPA Webfire for uncontrolled gasoline and diesel engines; therefore PM2.5 was conservatively assumed the same as PM10. CO2e includes CO2 emissions as well as CO2e emissions of CH4 and N2O calculated using GWP. Emission Factors for CO2, CH4 and N2O (lb/mmBtu) taken from EPA 40 CFR 98 Tables C‐1 and C‐2 as no other GHG emission factors are provided for this type of engine. The Permittee will follow the emergency only operating provisions of 40 CFR pt. 63, subp. ZZZZ. 3.2 Dispersion Modeling Per MPCA policy, as permitted in the original Part 70 permit, the facility triggered the requirement to submit modeling information. The company was not required to complete dispersion modeling. So, the Tier language does not apply. This modeling information will be used if required by nearby sources. 3.3 Monitoring In accordance with the Clean Air Act, it is the responsibility of the owner or operator of a facility to have sufficient knowledge of the facility to certify that the facility is in compliance with all applicable requirements. In evaluating the monitoring included in the permit, the MPCA considered the following:

the likelihood of the facility violating the applicable requirements;

whether add‐on controls are necessary to meet the emission limits;

the variability of emissions over time;

the type of monitoring, process, maintenance, or control equipment data already available for the emission unit;

the technical and economic feasibility of possible periodic monitoring methods; and

the kind of monitoring found on similar units elsewhere.


Table 6 summarizes the monitoring requirements.

Table 6. Monitoring Subject

Item* Requirement (basis) Monitoring Discussion

GP 001 (NOx

limit for EU

001 and EU

002)

NOx ≤ 244.0 tons

per year, on a 12

month rolling basis

(Facility‐wide limit

of 245 tons per year,

which includes

significant activities)

(limit to avoid NSR)

Recordkeeping:

Monthly records and

calculations of NOx

emissions. CEMS will

be used to measure

NOx emissions from

EU 002

This facility is a peaking plant. The plant is

intended for intermittent use rather than daily

usage; therefore, it is reasonable for this facility to

have monthly recordkeeping and calculation for

the source wide NOx limit than daily

recordkeeping.

NOx is the limiting pollutant for the entire facility;

therefore it is adequate to restrict and monitor

NOx emissions for purposes of avoiding NSR. By

limiting NOx emissions from the turbines, all other

pollutants will be limited as well; therefore, no

additional monitoring is warranted. One ton was

added for the insignificant activities.

The company will use CEM to measure NOx

emissions. Since the facility will not have the 5‐

10% buffer between the permitted emission limit

and the federal threshold, if the limit is relaxed at

any time, the facility will be subject to the

requirements of 40 CFR Section 52.21(r)(4).

EU 001

(Combustion

Turbine)

SO2: 0.50 lb/mmBtu

heat input

Opacity: ≤ 20 %

(Minn. R.

7011.2300)

Fuel Type: Pipeline

natural gas or No. 2

fuel oil/diesel fuel

(Minn. R.

7005.0100)

Fuel Monitoring

(CSAPR)

CMS: Fuel flow meter

will be used to record

and calculate NOx and

SO2 emissions for

CSAPR allowances

Fuel certification is no longer necessary for

compliance with Minn. R. 7011.2300. The fuel type

restriction will meet the requirements of 40 CFR

Section 80.510(c), of less than 15 parts per million

(ppm).

The Permittee will use the fuel flow meter as

described under 40 CFR Section 75.19 low mass

emission methodology to record and calculate NOx

and SO2 emissions for CSAPR based on its effective

date January 1, 2015.

The Permittee can demonstrate that the turbine

will continue to operate such that emissions are

well below the emission limits by burning natural

gas and sulfur fuel oil; therefore, no additional

monitoring is required.


Subject


Operating Scenarios

(Minn. R.

7007.0800)

There are three

operating Scenarios

for this unit

1. Daily and monthly

recordkeeping

2. Performance testing

3. CEMS

The company continues to operate under Scenario

1. The Permittee will record on a daily basis the

amounts of natural gas and fuel oil combusted in

the turbine. In addition, the Permittee will

calculate and record on a monthly basis the

amount of natural gas and fuel oil combusted. The

facility currently has a fuel flow monitor, which will

be used consistent with 40 CFR Section 75.19. The

other two scenarios are still viable.

EU 002

(Combustion

Turbine 002)

NOx: ≤ 15 ppm at

15% O2 when

operating at above

75% of peak loading

(NSPS, subp. KKKK)

Monitoring: CEMS will

be used to measure

NOx emissions

The CEMS was installed and operated in

accordance with the acid rain program (40 CFR pt.

75), which was allowed as a NOx monitoring

option. NOx performance test was done in 2007 to

calibrate the CEMS. The CEMS will be used to

monitor the NOx emission limits; therefore, no

additional monitoring will be required.

NOx: ≤ 96 ppm at

15% O2 when

operating less than

75% of peak loading

(NSPS, subp. KKKK)

SO2:≤0.90 lb/MWh

gross output

(NSPS, subp. KKKK)

Tariff sheet specifying

the maximum sulfur

content: ≤ 20

grains/100 scf.

EU 002 is connected to Northern Natural Gas

pipeline, which has a maximum sulfur content of

less than 20 grains/scf. By maintaining a current

tariff sheet as described in 40 CFR Section 60.4365,

the turbine is exempt from sulfur monitoring and

annual performance test requirements.

SO2: 0.50 lb/mmBtu

heat input

Opacity: ≤ 20 %

(Minn. R.

7011.2300)

None The NSPS limit (0.060 lb/mmBtu heat input) is

more stringent than Minn. R. SO2 limit; therefore

compliance will be demonstrated with the NSPS

limit.

Startup time:≤ 45

minutes


Recordkeeping‐Daily Recordkeeping is adequate to ensure CO emissions

are minimized during startup of the turbine.


Subject


EU 003

(Emergency

Diesel Fire

Pump

Engine)

SO2: 0.50 lb/mmBtu

heat input

Opacity: ≤ 20 %

(Minn. R.

7011.2300)

None Fuel certification no longer necessary for


will meet the requirements of 40 CFR Section

80.510(c), of less than 15 parts per million (ppm).

The Permittee can demonstrate that the turbine

will continue to operate such that emissions are

well below the emission limits by burning natural

gas and sulfur fuel oil; therefore, no additional

monitoring is required.

Hours of operation:

≤ 150 hours per year


Recordkeeping‐

Monthly

recordkeeping if

actual hours of

operating is greater

than 75 hours per year

in any calendar year

Monitoring actual hours of operation will ensure

NOx emissions to be minimized. Maintaining

monthly records over 75 operating hours will be

adequate to ensure NOx emissions will not exceed

major source thresholds.

Operating

Limitations

(NESHAP, subp.

ZZZZ)

Area Source NESHAP

(See Appendix D of

the permit)

Monitoring and recordkeeping as prescribed by the

NESHAPS, Subpart ZZZZ is adequate to ensure

continuous compliance.

EU 004

(Diesel

Starting

Engine)

SO2: 0.50 lb/mmBtu

heat input

Opacity: ≤ 20 %

(Minn. R.

7011.2300)

None Fuel certification is no longer necessary for


restriction will meet the requirements of 40 CFR

Section 80.510(c), of less than 15 parts per million

(ppm).

Hours of operation:

≤ 70 hours per year


Recordkeeping‐

Monthly

recordkeeping if

actual hours of

operating is greater

than 20 hours per year

in any calendar year

Monitoring actual hours of operation will ensure

NOx emissions to be minimized. Maintaining

monthly records over 20 operating hours will be

adequate to ensure NOx emissions will not exceed

major source thresholds.

Operating

Limitations

(NESHAP, subp.

ZZZZ)

Area Source NESHAP

(See Appendix D of

the permit)

Monitoring and recordkeeping as prescribed by the

NESHAPS, Subpart ZZZZ is adequate to ensure

continuous compliance.

*Location of the requirement in the permit (e.g., EU, SV, GP, etc.). 3.4 Insignificant Activities Great River Energy ‐ Cambridge has several operations which are classified as insignificant activities under the MPCA’s permitting rules. These are listed in Appendix C to the permit.


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

Table 7. Insignificant Activities

Insignificant Activity

General Applicable

Emission limit Discussion

Miscellaneous: brazing,

soldering or welding

equipment

[Facility performs some

brazing, soldering or welding

activities for plant

maintenance and repairs]

PM, variable depending

on airflow

Opacity ≤ 20%

(Minn. R.

7011.0710/0715)

For these units, based on EPA published emissions

factors, it is highly unlikely that they could violate

the applicable requirement. In addition, these units

are typically operated and vented inside a building,

so testing for PM or opacity is not feasible.

Individual units with

potential emissions less than

1) 4,000 lbs/year of CO; 2)

2,000 lbs/year each of NOx,

SO2, PM, PM10, VOCs and

ozone; and 3) 1,000 tpy of

CO2e.

[Telecom building LP generator SG020

Substation circuit breakers

SF6]


on airflow

Opacity ≤ 20% (with

exceptions)

(Minn. R. 7011.0715 and

Minn. R. 7011.0610)

or

SO2 ≤ 0.50 lb/MMBtu

Opacity ≤ 20%

(Minn. R. 7011.2300)

40 CFR pt. 63, subp. ZZZZ

There is a circuit breaker and an emergency

generator. The circuit breaker estimated emissions

are significant below the threshold for CO2e

emissions. The generator combusted very low

sulfur diesel; therefore based on the fuel used and

EPA published emissions factors, it is highly unlikely

that they could violate the applicable requirement.

The applicable requirements for the Telecom

building generator are listed in Appendix E of the

permit.

Fugitive Emissions

[Fugitive Emissions from

unpaved roads and parking

lots]

Requirement to take

reasonable measures to

prevent PM from

becoming airborne (Minn.

R. 7011.0150)

The Permittee will take reasonable precautions to

prevent the discharge of visible fugitive dust

emissions beyond the fence line of the property on

which the emissions will be generated.

Emissions units with actual

emissions of 1) 2 tpy CO; 2)

1 tpy each of NOx, SO2, PM.

PM10, VOCs and ozone; 3)

1,000 tpy CO2e.

[Parts washers – VOC actual

emissions less than 1 tpy]


on airflow

Opacity ≤ 20% (with

exceptions)

Minn. R. 7011.0710/0715

This is very small, intermittent, bench‐top

operation that typically does not even have any

emissions. It is highly unlikely that they could

violate the applicable requirements.


Insignificant Activity

General Applicable

Emission limit Discussion

Emissions units with actual

emissions of 1) 2 tpy CO; 2)

1 tpy each of NOx, SO2, PM.

PM10, VOCs and ozone; 3)

1,000 tpy CO2e.

[150,000 gals fuel oil storage

tank and associated piping]

Minn. R. 7011.1505

There are no standards of performance applicable

for storage vessels/tanks.

3.5 Permit Organization In general, the permit meets the MPCA Delta Guidance for ordering and grouping of requirements. One area where this permit deviates slightly from Delta guidance is in the use of appendices. While appendices are fully enforceable parts of the permit, in general, any requirement that the MPCA thinks should be electronically tracked (e.g., limits, submittals, etc.), should be in Table A or B of the permit. The main reason is that the appendices are word processing sections and are not part of the electronic tracking system. Violation of the appendices can be enforced, but the computer system will not automatically generate the necessary enforcement notices or documents. Staff must generate these. Another area that deviates from the guidance is in the use of groups where the requirements in the group apply to the members of the group individually. This was done in order to shorten the permit and where no testing or tracking specific to a unit is in the permit (thereby reducing the likelihood that there where will be further unit‐specific requirements later). This is the case for the requirements at GP 001(combined NOx limit) and GP 002 (continuous emission monitors). 3.6 Comments Received Public Notice Period: <start date> ‐ <end date> EPA 45‐day Review Period: <start date> ‐ <end date> This section will be completed after the referenced review periods above. 4. Permit Fee Assessment This permit action is the reissuance of an individual Part 70; therefore, no application fees apply under Minn. R. 7002.0016, subp. 1. There are no additional points required by this permit action. 5. Conclusion Based on the information provided by Great River Energy, the MPCA has reasonable assurance that the proposed operation of the emission facility, as described in the Air Emission Permit No. 05900014‐004 and this TSD, will not cause or contribute to a violation of applicable federal regulations and Minnesota Rules. Staff Members on Permit Team: Amrill Okonkwo (permit engineer)

David Crowell (compliance and enforcement)


Tarik Hanafy (peer reviewer) Beckie Olson (permit writing assistant) Laurie O’Brien (administrative support)

AQ File No. 147C; DQ 4275 Attachments: 1. PTE Summary Calculation Spreadsheets

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

Attachment 1 – PTE Summary Calculation Spreadsheets (Available electronically in the Central File of Delta)

Attachment 2‐ Facility Description and CD‐01 Forms (Available electronically in the Central File of Delta)

Attachment 3‐ Points Calculator

(Available electronically in an excel spreadsheet in the Central File of Delta)

Attachment 1- PTE Summary Calculation Spreadsheets

Gre

at R

iver

Ene

rgy

- Cam

brid

geE

miss

ion

Cal

cula

tions

Max

imum

Em

issi

onE

mis

sion

Ope

ratin

gPo

tent

ial t

oO

pera

ting

Pote

ntia

l to

Uni

tH

eat I

nput

Rat

eR

ate

Hou

rsE

mit

(PT

E)

Hou

rsE

mit

(PT

E)

IDU

nit N

ame

Fuel

Pollu

tant

(MM

Btu

/hr)

(lb/h

r)(g

/s)

(hr/

yr)

(ton/

yr)

(hr/

yr)

(ton/

yr)

001

Uni

t 1N

at. G

asV

OC

363.

32.

10E

-03

20.

89.

61E

-02

8760

3.3

4197

1.6

001

Uni

t 1N

at. G

asPM

363.

36.

60E

-03

22.

43.

02E

-01

8760

10.5

4197

5.0

001

Uni

t 1N

at. G

asPM

1036

3.3

6.60

E-0

32

2.4

3.02

E-0

187

6010

.541

975.

000

1U

nit 1

Nat

. Gas

PM2.

536

3.3

1.90

E-0

38

0.7

8.70

E-0

287

603.

041

971.

400

1U

nit 1

Nat

. Gas

CO

363.

38.

20E

-02

229

.83.

75E

+00

8760

130.

541

9762

.500

1U

nit 1

Nat

. Gas

SO2

363.

39.

15E

-05

20.

034.

19E

-03

8760

0.1

4197

0.07

000

1U

nit 1

Nat

. Gas

H2S

O4

Mis

t36

3.3

1.83

E-0

65

0.00

078.

37E

-05

8760

0.00

341

970.

0014

001

Uni

t 1N

at. G

asN

OX

363.

33.

20E

-01

211

61.

46E

+01

8760

509.

241

9724

4.0

001

Uni

t 1N

at. G

asC

O2e

363.

31.

17E

+02

742

,509

5.36

E+

0387

6018

6,19

041

9789

,206

001

Uni

t 1N

at. G

as1,

3-B

utad

iene

363.

34.

30E

-07

21.

6E-0

41.

97E

-05

8760

0.00

141

970.

0003

001

Uni

t 1N

at. G

asA

ceta

ldeh

yde

363.

34.

00E

-05

21.

5E-0

21.

83E

-03

8760

0.06

441

970.

030

001

Uni

t 1N

at. G

asA

crol

ein

363.

36.

40E

-06

22.

3E-0

32.

93E

-04

8760

0.01

041

970.

005

001

Uni

t 1N

at. G

asB

enze

ne36

3.3

1.20

E-0

52

4.4E

-03

5.49

E-0

487

600.

019

4197

0.00

900

1U

nit 1

Nat

. Gas

Eth

yl b

enze

ne36

3.3

3.20

E-0

52

1.2E

-02

1.46

E-0

387

600.

051

4197

0.02

400

1U

nit 1

Nat

. Gas

Form

alde

hyde

363.

37.

10E

-04

22.

6E-0

13.

25E

-02

8760

1.13

041

970.

5400

1U

nit 1

Nat

. Gas

Nap

htha

lene

363.

31.

30E

-06

24.

7E-0

45.

95E

-05

8760

0.00

241

970.

0009

900

1U

nit 1

Nat

. Gas

PAH

363.

32.

20E

-06

28.

0E-0

41.

01E

-04

8760

0.00

441

970.

0016

800

1U

nit 1

Nat

. Gas

Prop

ylen

e ox

ide

363.

32.

90E

-05

21.

1E-0

21.

33E

-03

8760

0.04

641

970.

022

001

Uni

t 1N

at. G

asT

olue

ne36

3.3

1.30

E-0

42

4.7E

-02

5.95

E-0

387

600.

207

4197

0.09

900

1U

nit 1

Nat

. Gas

Xyl

enes

363.

36.

40E

-05

22.

3E-0

22.

93E

-03

8760

0.10

241

970.

049

Tota

l HAP

3.7E

-01

4.70

E-0

21.

635

7.8E

-01

001

Uni

t 1D

is. O

ilV

OC

363.

34.

10E

-04

21.

5E-0

11.

88E

-02

8760

0.65

215

260.

114

001

Uni

t 1D

is. O

ilPM

363.

31.

20E

-02

24.

365.

49E

-01

8760

19.0

9515

263.

326

001

Uni

t 1D

is. O

ilPM

1036

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4.30

E-0

32

1.56

1.97

E-0

187

606.

842

1526

1.19

200

1U

nit 1

Dis

. Oil

PM2.

536

3.3

1.11

E-0

28

4.02

5.07

E-0

187

6017

.615

1526

3.06

900

1U

nit 1

Dis

. Oil

CO

363.

33.

30E

-03

21.

201.

51E

-01

8760

5.25

115

260.

915

001

Uni

t 1D

is. O

ilSO

236

3.3

5.05

E-0

22

18.3

52.

31E

+00

8760

80.3

5815

2613

.998

001

Uni

t 1D

is. O

ilH

2SO

4 M

ist

363.

31.

01E

-03

50.

374.

62E

-02

8760

1.60

715

260.

280

001

Uni

t 1D

is. O

ilN

OX

363.

38.

80E

-01

231

9.70

4.03

E+

0187

6014

00.3

0415

2624

3.93

400

1U

nit 1

Dis

. Oil

CO

2e36

3.3

1.64

E+

027

59,4

357,

489

8760

260,

327

1526

45,3

4900

1U

nit 1

Dis

. Oil

1,3

-but

adie

ne36

3.3

1.60

E-0

52

5.8E

-03

7.32

E-0

487

600.

025

1526

0.00

400

1U

nit 1

Dis

. Oil

Ben

zene

363.

35.

50E

-05

22.

0E-0

22.

52E

-03

8760

0.08

815

260.

015

001

Uni

t 1D

is. O

ilFo

rmal

dehy

de36

3.3

2.80

E-0

42

1.0E

-01

1.28

E-0

287

600.

446

1526

0.07

800

1U

nit 1

Dis

. Oil

Nap

htha

lene

363.

33.

50E

-05

21.

3E-0

21.

60E

-03

8760

0.05

615

260.

010

001

Uni

t 1D

is. O

ilPA

H36

3.3

4.00

E-0

52

1.5E

-02

1.83

E-0

387

600.

064

1526

0.01

100

1U

nit 1

Dis

. Oil

Ars

enic

363.

31.

10E

-05

24.

0E-0

35.

04E

-04

8760

0.01

815

260.

003

001

Uni

t 1D

is. O

ilB

eryl

lium

363.

33.

10E

-07

21.

1E-0

41.

42E

-05

8760

0.00

015

260.

000

001

Uni

t 1D

is. O

ilC

adm

ium

363.

34.

80E

-06

21.

7E-0

32.

20E

-04

8760

0.00

815

260.

001

001

Uni

t 1D

is. O

ilC

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ium

363.

31.

10E

-05

24.

0E-0

35.

04E

-04

8760

0.01

815

260.

003

001

Uni

t 1D

is. O

ilL

ead

363.

31.

40E

-05

25.

1E-0

36.

41E

-04

8760

0.02

215

260.

004

001

Uni

t 1D

is. O

ilM

anga

nese

363.

37.

90E

-04

22.

9E-0

13.

62E

-02

8760

1.25

715

260.

219

001

Uni

t 1D

is. O

ilM

ercu

ry36

3.3

1.20

E-0

62

4.4E

-04

5.49

E-0

587

600.

002

1526

0.00

000

1U

nit 1

Dis

. Oil

Nic

kel

363.

34.

60E

-06

21.

7E-0

32.

11E

-04

8760

0.00

715

260.

001

001

Uni

t 1D

is. O

ilSe

leni

um36

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E-0

52

9.1E

-03

1.14

E-0

387

600.

040

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0.00

7

Em

issi

on F

acto

r(lb

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Gre

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Max

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(PT

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ame

Fuel

Pollu

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(MM

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/hr)

(lb/h

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(hr/

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(ton/

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(hr/

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Em

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on F

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9.4

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84E

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84E

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114

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83E

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1850

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3.5

4.43

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187

6015

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Nat

. Gas

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1850

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21

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4.66

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509.

15E

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1850

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21

1.69

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2.73

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8,12

228

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2,46

900

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. Gas

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Great River Energy - Cambridge Emission Calculations

Great River EnergyFacility CambridgePermit# 5900014Unit# EU003 (Diesel Driven Fire Pump Package FM-DFPS-3650)Fire Pump Eng. JU6H-UFG8 (Clarke)Model 6068TF220 (John Deere)Rated Input 9.50 gal/hr #2 Fuel OilRated Input 1.3205 MMbtu/hr (@0.139 MMbtu/gal)Rated Output 149 bhp

EmissionFactor (1)

EmissionRate

Potential to Emit (2)

RestrictedEmissions (3)

(lb/hr) (tpy) (tpy)

PM (a) 0.19 0.217 0.952 0.016PM10 (a) 0.19 0.217 0.952 0.016PM2.5 (c) 0.19 0.217 0.952 0.016SOx (b) 0.29 0.383 1.677 0.029CO2e (d) 215 943 16.15NOx (a) 4.99 5.708 25.001 0.428VOC (b) 0.36 0.475 2.082 0.036CO (a) 0.33 0.377 1.653 0.028Lead (b) 0.00 0.00 0.00 0.000NMHC (a) 0.21 0.240 1.052 0.018

EmissionFactor

(lb/MMBtu) Emission Rate Potential to EmitRestrictedEmissions

CO2 163.05 215.308 943.047 16.148CH4 0.01 0.009 0.038 0.000NO2 0.00 0.002 0.008 0.000

EmissionFactor (4)

EmissionRate



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

1,3-Butadiene 3.91E-05 5.16E-05 2.26E-04 3.87E-06Acetaldehyde 7.67E-04 1.01E-03 4.44E-03 7.60E-05Acrolein (c) 9.25E-05 1.22E-04 5.35E-04 9.16E-06Benzene 9.33E-04 1.23E-03 5.40E-03 9.24E-05Formaldehyde 1.18E-03 1.56E-03 6.82E-03 1.17E-04Naphthalene 8.48E-05 1.12E-04 4.90E-04 8.40E-06Total PAH 1.68E-04 2.22E-04 9.72E-04 1.66E-05Toluene 4.09E-04 5.40E-04 2.37E-03 4.05E-05Xylenes 2.85E-04 3.76E-04 1.65E-03 2.82E-05Mercury(5) 3.01E-07 3.98E-07 1.74E-06 2.98E-08

1) a - Emission factors supplied by manufacturer (grams/hp-hr).(1 hp-hr = 2,545 Btu, #2 Oil = 139,000 Btu/gal, 453.59 gram = 1 lb)

b - Emission factors from MPCA Table EC-03.1 Reciprocating Engine <600 hp Diesel/

USEPA AP-42 Table 3.3-1: Emission Factors for Uncontrolled Gasoline and Diesel Industrual Engines (lb/MMBtu). http://www.epa.gov/ttn/chief/ap42/ch03/final/c03s03.pdf

c - Manufacturer does not supply an emission factor for PM2.5. It can be reasonably assumed that the emission

factor will be the same as PM10

d - CO2e includes CO2 emissions as well as CO2e emissions of CH4 and N2O calculated using GWP. Emission Factors for CO2, CH4 and N2O (lb/mmBtu) taken from EPA 40 CFR 98 Tables C-1 and C-2 as no other GHG emission factors are provided for

P:\23\19\845\Air\Emissions\Calcs\Worksheet in ole_main Page 4 of 12 Printed 4/21/2015


this type of engine.

2) Potential to emit is calculated at 8760 hr/yr since the EPA emergency generator memo does not apply to fire pumps.

3) This emission source has restricted emissions to 150 hours per year.

4) USEPA AP-42 Table 3.3-2: Speciated Organic Compound Emission Factors for Uncontrolled Diesel Engines.

c - less than 9.25E-05 lb/MMBtu http://www.epa.gov/ttn/chief/ap42/ch03/final/c03s03.pdf

5) Hg emission factor from WebFire for SIC 20200102



Great River EnergyFacility Cambridge

Permit# 5900014

Unit# EU004 -Diesel Starting Engine

Diesel Start Eng. Massaro Detroit Diesel Alison

Model 7123-7000 V12 #2 Fuel Oil

Rated Output 500.00 hp Rated Input (5) 3.5 mmBtu/hr

EmissionFactor (1)

EmissionRate



lb/hp-hr lb/hr tpy tpy

PM 2.20E-03 1.100 4.818 0.039

PM10 2.20E-03 1.100 4.818 0.039

PM2.5 (a) 2.20E-03 1.100 4.818 0.039

SOx 2.05E-03 1.025 4.490 0.036

NOx 3.10E-02 15.50 67.89 0.543

CO2e (b) 571 2499.68 19.97

VOC 2.51E-03 1.257 5.506 0.044

CO 6.68E-03 3.340 14.63 0.117

Lead 0.00 0.00 0.00 0.000Emission

Factor(lb/MMBtu) Emission Rate Potential to Emit

RestrictedEmissions

CO2 163.05 570.675 2499.557 19.974CH4 0.01 0.023 0.101 0.001NO2 0.00 0.005 0.020 0.000

EmissionFactor (4)

EmissionFactor

EmissionRate



lb/MMBtu lb/hp-hr lb/hr tpy tpy

Benzene 9.33E-04 6.53E-06 3.27E-03 1.43E-02 1.14E-04 Toluene 4.09E-04 2.86E-06 1.43E-03 6.27E-03 5.01E-05 Xylenes 2.85E-04 2.00E-06 9.98E-04 4.37E-03 3.49E-05 1,3-Butadiene 3.91E-05 2.74E-07 1.37E-04 5.99E-04 4.79E-06 Formaldehyde 1.18E-03 8.26E-06 4.13E-03 1.81E-02 1.45E-04 Acetaldehyde 7.67E-04 5.37E-06 2.68E-03 1.18E-02 9.40E-05 Acrolein (a) 9.25E-05 6.48E-07 3.24E-04 1.42E-03 1.13E-05 Naphthalene 8.48E-05 5.94E-07 2.97E-04 1.30E-03 1.04E-05 Mercury (6) 3.01E-07 2.11E-09 1.05E-06 4.62E-06 3.69E-08Total PAH 1.68E-04 1.18E-06 5.88E-04 2.58E-03 2.06E-05

1) Emission factors are from MPCA Table EC-03.1 Reciprocating Engine <600 hp Diesel USEPA AP-42 Table 3.3-1: Emission Factors for Uncontrolled Gasoline and Diesel Industrual Engines (lb/MMBtu). http://www.epa.gov/ttn/chief/ap42/ch03/final/c03s03.pdf

a - No emission factor for PM2.5 is provided in AP-42 or EPA WebFire for Uncontrolled Gasoline and Diesel Engines It can be reasonably assumed that the emission factor will be the same as PM10 b - CO2e includes CO2 emissions as well as CO2e emissions of CH4 and N2O calculated using GWP. Emission Factors for CO2, CH4 and N2O taken from EPA 40 CFR 98 Tables C-1 and C-2 as no other GHG emission factors are provided for this type of engine. An average brake-specific fuel consumption (BSFC) of



7,000 Btu/hp-hr was used to convert from lb/MMBtu to lb/hp-hr.2) Potential to emit is calculated at 8760 since the EPA emergency generator memo does not apply to starting engines3) This emission source has restricted emissions to 70 hours per year.4) USEPA AP-42 Table 3.3-2: Speciated Organic Compound Emission Factors for Uncontrolled Diesel Engines. http://www.epa.gov/ttn/chief/ap42/ch03/final/c03s03.pdf

An average brake-specific fuel consumption (BSFC) of 7,000 Btu/hp-hr was used to convert from lb/MMBtu to lb/hp-hr. a - less than 9.25E-05 lb/MMBtu5) An average brake-specific fuel consumption (BSFC) of 7,000 Btu/hp-hr was used to convert hp to mmBtu/hr6) Hg emission factor from WebFire for SIC 20200102


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CH

40.

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5037

41.

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1.50

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1.50

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02

Great River EnergyCambridge Turbines (EU001 and EU002)Permit #05900014

GP001 at 244 tpy

EU001/EU002 EU003 EU004

TPY TPY TPY

1,3 -butadiene 4.44E-03 3.91E-06 4.79E-06

Acetaldehyde 1.07E-01 7.68E-05 9.40E-05

Acrolein 1.71E-02 9.26E-06 8.09E-05

Arsenic 3.05E-03

Benzene 3.20E-02 9.34E-05 1.14E-04

Beryllium 8.59E-05

Cadmium 1.33E-03

Chromium 3.05E-03

Ethyl benzene 8.55E-02

Formaldehyde 1.90E+00 1.18E-04 1.45E-04H2SO4 Mist 2.80E-01

Lead 3.88E-03

Manganese 2.19E-01

Mercury 3.33E-04 3.02E-08 2.64E-07

Naphthalene 9.70E-03 8.49E-06 7.42E-05

Nickel 1.28E-03

Propylene oxide 7.74E-02

Selenium 6.93E-03

Toluene 3.47E-01 4.09E-05 5.01E-05

Xylenes 1.71E-01 2.85E-05 3.49E-05

Total PAHs 5.88E-03 5.55E-05 2.06E-05

Total 2.74E+00 3.79E-04 5.98E-04 2.74E+00

Facility Limited at 245 tpy NOX

limited to 1 tpy combined

Worksheet in ole_main 4/21/2015

EU 001 and EU 002

Worst Case Emissions when NOX is limited to 244 tpy tpyPM Emissions 20.931

PM10 Emissions 20.931

PM2.5 Emissions 5.074

SO2 Emissions 13.998

CO2 Emissions 312,469

VOC Emissions 13.569

CO Emissions [6] 122.000

H2SO4 Mist Emissions 0.280

Limited NOX Emissions 244.000

Total HAP Emissions 2.743

Single HAP Emissions (Formaldehyde) 1.896

EU 003

PM (a) 0.016

PM10 (a) 0.016

PM2.5 (a) 0.016

SOx (b) 0.029

NOx (a) 0.428

CO2 (b) 16

VOC (b) 0.036

CO (a) 0.028

Lead (b) 0.000

NMHC (a) 0.018

Formaldehyde 0.000

EU 004PM 0.039PM10 0.039PM2.5 0.039SOx 0.036NOx 0.543CO2 19.975VOC 0.044CO 0.117Formaldehyde 0.000

TotalsPM 21.0PM10 21.0PM2.5 5.1SO2 14.1NOX 225.0CO2 312,505NO2 4.01CH4 19.59

CO2e 312528.54VOCs 13.6CO 122.1Formaldehyde 1.9Total HAPs 2.7

Attachment 2- Facility Description and CD-01 Forms

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21 April, 2015 11:19

Show: Active and Pending Records

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

RetiredBy

(Action)

AddedBy

(Action)

ItemPollutant ActualEmissions

(tons per yr)

LimitedPotential

(tons per yr)

UnrestrictedPotential

(tons per yr)

HourlyPotential

(lbs per hr)

AQD Facility ID: 05900014

Facility Name: Great River Energy - Cambridge

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

Acetaldehyde

PER 003EU 001 1.500E-02 6.400E-02 0.000E+00

PER 003EU 002 7.400E-02 3.240E-01 0.000E+00

PER 003EU 003 1.042E-03 4.564E-03 0.000E+00

PER 003EU 004 2.685E-03 1.176E-02 0.000E+00

PER 003GP 001 7.400E-02 3.241E-01 1.068E-01

PER 004GP 001 7.400E-02 3.241E-01 1.070E-01

Totals 7.284E-01 1.070E-01 0.000E+00

Acrolein

PER 003EU 001 2.300E-03 1.000E-02 0.000E+00

PER 003EU 002 1.200E-02 5.200E-02 0.000E+00

PER 003EU 003 1.257E-04 5.504E-04 0.000E+00

PER 003EU 004 3.238E-04 1.418E-03 0.000E+00

PER 003GP 001 1.184E-02 5.186E-02 1.709E-02

PER 004GP 001 1.184E-02 5.186E-02 1.700E-02

Totals 1.158E-01 1.700E-02 0.000E+00

Benzene

PER 003EU 001 2.000E-02 8.800E-02 0.000E+00

PER 003EU 002 2.200E-02 9.700E-02 0.000E+00

PER 003EU 003 1.267E-03 5.552E-03 0.000E+00

PER 003EU 004 3.266E-03 1.430E-02 0.000E+00

PER 003GP 001 2.220E-02 9.724E-02 3.205E-02

PER 004GP 001 2.220E-02 9.724E-02 3.200E-02

Totals 3.021E-01 3.200E-02 0.000E+00

Arsenic compounds

PER 003EU 001 4.000E-03 1.800E-02 0.000E+00

PER 003GP 001 3.996E-03 1.750E-02 3.049E-03

Totals 3.550E-02 3.049E-03 0.000E+00

1,3-Butadiene

PER 003EU 001 5.800E-03 2.500E-02 0.000E+00

PER 003EU 002 8.000E-04 3.000E-03 0.000E+00

PER 003EU 003 5.312E-05 2.327E-04 0.000E+00 0.000E+00

PER 003EU 004 1.369E-04 5.994E-04 0.000E+00

PER 003GP 001 5.813E-03 2.546E-02 4.435E-03

Totals 5.429E-02 4.435E-03 0.000E+00

Beryllium

PER 003EU 001 1.100E-04 1.000E-04 0.000E+00

Page 1 of 6

21 April, 2015 11:19



RetiredBy

(Action)

AddedBy

(Action)


(tons per yr)

LimitedPotential

(tons per yr)


(tons per yr)

HourlyPotential

(lbs per hr)




Beryllium

PER 003GP 001 1.126E-04 4.933E-04 8.593E-05

Totals 5.933E-04 8.593E-05 0.000E+00

Carbon Dioxide Equivalent

PER 004EU 001 4.251E+04 1.862E+05 1.563E+05

PER 004EU 002 9.471E+05 4.148E+06 1.563E+05

PER 004EU 003 2.150E+02 9.430E+02 1.615E+01

PER 004EU 004 5.710E+02 2.500E+03 1.997E+01

PER 004EU 005 2.039E+01 8.930E+01 5.100E+00

Totals 4.338E+06 3.126E+05 0.000E+00

Cadmium compounds

PER 003EU 001 1.700E-03 8.000E-03 0.000E+00

PER 003GP 001 1.744E-03 7.638E-03 1.331E-03

Totals 1.564E-02 1.331E-03 0.000E+00

Methane

PER 004EU 001 7.260E-01 3.200E+00 3.200E+00

PER 004EU 002 3.700E+00 1.620E+01 1.620E+01

PER 004EU 003 9.000E-03 3.800E-02 0.000E+00

PER 004EU 004 2.000E-03 8.000E-03 0.000E+00

Totals 1.945E+01 1.940E+01 0.000E+00

Carbon Monoxide

PER 003EU 001 2.980E+01 1.305E+02 0.000E+00 4.000E-03

PER 004EU 001 2.980E+01 1.305E+02 0.000E+00

PER 003EU 002 3.700E+01 1.621E+02 0.000E+00

PER 003EU 003 3.883E-01 1.701E+00 2.800E-02

PER 003EU 004 3.340E+00 1.463E+01 1.170E-01

PER 003GP 001 3.700E+01 1.621E+02 1.220E+02

Totals 4.710E+02 1.221E+02 0.000E+00

Carbon Dioxide

PER 004EU 001 3.567E+04 1.563E+05 1.563E+05

PER 004EU 002 3.567E+04 1.563E+05 1.563E+05

PER 004EU 003 5.707E+02 2.500E+03 1.997E+01

PER 004EU 004 2.153E+02 9.430E+02 1.615E+01

Totals 3.159E+05 3.125E+05 0.000E+00

Chromium compounds

PER 003EU 001 4.000E-03 1.800E-02 0.000E+00

Page 2 of 6

21 April, 2015 11:19



RetiredBy

(Action)

AddedBy

(Action)


(tons per yr)

LimitedPotential

(tons per yr)


(tons per yr)

HourlyPotential

(lbs per hr)




Chromium compounds

PER 003GP 001 3.996E-03 1.750E-02 3.049E-03

Totals 3.550E-02 3.049E-03 0.000E+00

Ethylbenzene

PER 003EU 001 1.200E-02 5.100E-02 0.000E+00

PER 003EU 002 5.900E-02 2.590E-01 0.000E+00

PER 003GP 001 5.920E-02 2.593E-01 8.546E-02

Totals 5.693E-01 8.546E-02 0.000E+00

Formaldehyde

PER 003EU 001 2.600E-01 1.130E+00 0.000E+00

PER 003EU 002 1.300E+00 5.753E+00 0.000E+00

PER 003EU 003 1.603E-03 7.021E-03 0.000E+00

PER 003EU 004 4.130E-03 1.809E-02 0.000E+00

PER 003GP 001 1.314E+00 5.753E+00 1.896E+00

Totals 1.266E+01 1.896E+00 0.000E+00

Naphthalene

PER 003EU 001 1.300E-02 5.600E-02 0.000E+00

PER 003EU 002 2.400E-03 1.100E-02 0.000E+00

PER 003EU 003 1.152E-04 5.046E-04 0.000E+00

PER 003EU 004 2.968E-04 1.300E-03 0.000E+00

PER 003GP 001 1.272E-02 5.569E-02 9.702E-03

Totals 1.245E-01 9.702E-03 0.000E+00

HAPs - Total

PER 003EU 001 4.700E-01 2.050E+00 0.000E+00

PER 003EU 002 2.033E+00 8.320E+00 0.000E+00

PER 003GP 001 1.901E+00 8.324E+00 2.743E+00

Totals 1.869E+01 2.743E+00 0.000E+00

Mercury

PER 003EU 001 4.400E-04 2.000E-03 0.000E+00

PER 003EU 003 4.095E-07 1.793E-06 0.000E+00

PER 003EU 004 1.055E-06 4.621E-06 0.000E+00

PER 003GP 001 4.360E-04 1.910E-03 3.326E-04

Totals 3.916E-03 3.326E-04 0.000E+00

Propylene oxide

PER 003EU 001 1.100E-02 4.600E-02 0.000E+00

PER 003EU 002 5.400E-02 2.350E-01 0.000E+00

Page 3 of 6

21 April, 2015 11:19



RetiredBy

(Action)

AddedBy

(Action)


(tons per yr)

LimitedPotential

(tons per yr)


(tons per yr)

HourlyPotential

(lbs per hr)




Propylene oxide

PER 003GP 001 5.365E-02 2.350E-01 7.744E-02

Totals 5.160E-01 7.744E-02 0.000E+00

Toluene

PER 003EU 001 4.700E-02 2.070E-01 0.000E+00

PER 003EU 002 2.400E-01 1.053E+00 0.000E+00

PER 003EU 003 5.556E-04 2.434E-03 0.000E+00

PER 003EU 004 1.432E-03 6.270E-03 0.000E+00

PER 003GP 001 2.405E-01 1.053E+00 3.472E-01

Totals 2.322E+00 3.472E-01 0.000E+00

Xylenes (mixed isomers)

PER 003EU 001 2.300E-02 1.020E-01 0.000E+00

PER 003EU 002 1.200E-01 5.190E-01 0.000E+00

PER 003EU 003 3.872E-04 1.696E-03 0.000E+00

PER 003EU 004 9.975E-04 4.369E-03 0.000E+00

PER 003GP 001 1.184E-01 5.186E-01 1.709E-01

Totals 1.146E+00 1.709E-01 0.000E+00

Manganese compounds

PER 003EU 001 2.900E-01 1.257E+00 0.000E+00

PER 003GP 001 2.870E-01 1.257E+00 2.190E-01

Totals 2.514E+00 2.190E-01 0.000E+00

Nitrous Oxide

PER 004EU 001 3.630E-05 3.000E-01 3.000E-01

PER 004EU 002 1.850E-04 1.621E+00 1.621E+00

PER 004EU 003 7.900E-07 2.068E+00 2.068E+00

PER 004EU 004 2.100E-06 1.840E-02 1.840E-02

Totals 4.007E+00 4.007E+00 0.000E+00

Total Polycyclic aromatic hydr

PER 003EU 003 2.282E-04 9.996E-04 0.000E+00

PER 003EU 004 5.880E-04 2.575E-03 0.000E+00

Totals 3.575E-03 0.000E+00 0.000E+00

Nickel compounds

PER 003EU 001 1.700E-03 7.000E-03 0.000E+00

PER 003GP 001 1.671E-03 7.320E-03 1.275E-03

Totals 1.432E-02 1.275E-03 0.000E+00

Nitrogen Oxides

PER 003EU 001 3.200E+02 1.400E+03 0.000E+00 1.142E+00

Page 4 of 6

21 April, 2015 11:19



RetiredBy

(Action)

AddedBy

(Action)


(tons per yr)

LimitedPotential

(tons per yr)


(tons per yr)

HourlyPotential

(lbs per hr)




Nitrogen Oxides

PER 004EU 001 3.200E+02 1.400E+03 0.000E+00

PER 003EU 002 1.690E+02 7.402E+02 0.000E+00 0.000E+00

PER 004EU 002 1.690E+02 7.400E+02 0.000E+00 0.000E+00

PER 003EU 003 5.872E+00 2.572E+01 4.280E-01 0.000E+00

PER 004EU 003 5.710E+00 2.500E+01 0.000E+00 0.000E+00

PER 003EU 004 1.550E+01 6.789E+01 5.430E-01 0.000E+00

PER 004EU 004 1.550E+01 6.789E+01 0.000E+00 0.000E+00

PER 004EU 005 2.300E-01 1.071E+00 0.000E+00

PER 003GP 001 3.197E+02 1.400E+03 2.440E+02 0.000E+00

PER 004GP 001 2.450E+02 0.000E+00

Totals 2.234E+03 2.450E+02 0.000E+00

PM < 2.5 micron

PER 004EU 001 7.000E-01 3.000E+00 0.000E+00

PER 004EU 002 3.500E+00 1.540E+01 0.000E+00

PER 004EU 003 2.236E-02 9.793E-01 1.600E-03

PER 004EU 004 1.100E+00 4.818E+00 3.900E-03

PER 004GP 001 3.500E+00 1.540E+01 5.100E+00

Totals 3.960E+01 5.106E+00 0.000E+00

Lead

PER 003EU 001 5.100E-03 2.200E-02 0.000E+00 0.000E+00

PER 003GP 001 5.086E-03 2.228E-02 3.881E-03

Totals 4.428E-02 3.881E-03 0.000E+00

PM < 10 micron

PER 003EU 001 2.400E+00 1.050E+01 0.000E+00 3.100E-02

PER 004EU 001 2.400E+00 1.050E+01 0.000E+00

PER 003EU 002 2.400E+00 6.350E+01 0.000E+00 0.000E+00

PER 004EU 002 1.450E+01 6.350E+01 0.000E+00 0.000E+00

PER 003EU 003 2.236E-01 9.793E-01 1.600E-02 0.000E+00

PER 003EU 004 1.100E+00 4.818E+00 3.900E-02 0.000E+00

PER 003GP 001 1.450E+01 6.351E+01 2.093E+01 0.000E+00

PER 004GP 001 1.450E+01 6.350E+00 2.090E+01 0.000E+00

Totals 8.615E+01 2.096E+01 0.000E+00

Total Particulate Matter

PER 003EU 001 4.400E+00 1.910E+01 0.000E+00 3.100E-02

PER 004EU 001 4.400E+00 1.910E+01 0.000E+00

PER 003EU 002 1.450E+01 6.350E+01 0.000E+00

Page 5 of 6

21 April, 2015 11:19



RetiredBy

(Action)

AddedBy

(Action)


(tons per yr)

LimitedPotential

(tons per yr)


(tons per yr)

HourlyPotential

(lbs per hr)




Total Particulate Matter

PER 003EU 003 2.236E-01 9.793E-01 1.600E-02

PER 003EU 004 1.100E+00 4.818E+00 3.900E-02

PER 003GP 001 1.450E+01 6.351E+01 2.093E+01

Totals 1.519E+02 2.099E+01 0.000E+00

Sulfuric Acid Mist

PER 003EU 001 3.700E+00 1.607E+01 0.000E+00

PER 003EU 002 3.400E-03 1.500E-02 0.000E+00

PER 003GP 001 3.669E+00 1.607E+01 2.800E+00

PER 004GP 001 3.700E+00 1.607E+00 2.800E+00

Totals 1.769E+01 2.800E+00 0.000E+00

Selenium compounds

PER 003EU 001 9.100E-03 4.000E-02 0.000E+00

PER 003GP 001 9.083E-03 3.978E-02 6.930E-03

Totals 7.978E-02 6.930E-03 0.000E+00

Sulfur Dioxide

PER 003EU 001 1.800E+02 8.036E+02 0.000E+00 1.300E-01

PER 004EU 001 1.800E+02 8.036E+02 0.000E+00 0.000E+00

PER 003EU 002 2.000E-01 7.000E-01 0.000E+00 0.000E+00

PER 003EU 003 3.940E-01 1.726E+00 2.900E-02 0.000E+00

PER 003EU 004 1.025E+00 4.490E+00 3.600E-02 0.000E+00

PER 003GP 001 1.835E+02 8.036E+02 1.400E+02 0.000E+00

PER 004GP 001 1.835E+02 8.036E+02 1.400E+02 0.000E+00

Totals 1.614E+03 1.401E+02 0.000E+00

Volatile Organic Compounds

PER 003EU 001 8.000E-01 3.300E+00 0.000E+00 1.000E-03

PER 004EU 001 8.000E-01 3.300E+00 0.000E+00

PER 003EU 002 9.400E+00 4.120E+01 0.000E+00

PER 003EU 003 4.890E-01 2.142E+00 3.600E-02

PER 003EU 004 1.257E+00 5.506E+00 4.400E-02

PER 003GP 001 9.400E+00 4.117E+01 1.357E+01

Totals 9.332E+01 1.365E+01 0.000E+00

Page 6 of 6

MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01


Permit Number: 05900014 - 004

21 Apr, 2015 11:26Page 1 of 15

Subject Item: Total Facility

NC/CA

Type Citation Requirement

CD Minn. R. 7007.0800, subp. 2 FACILITY SUBJECT TO TRANSPORT RULE(TR) /CROSS-STATE AIRPOLLUTION RULE (CSAPR)

1.0

CD 40 CFR pt. 97; 40 CFR 52.1240;40 CFR 52.38

The Permittee shall comply with all applicable requirements of 40 CFR pt. 97 forTransport Rule (TR) NOx Annual Units and a TR NOx Annual Source, described in40 CFR Section 97.404.

2.0

CD 40 CFR pt. 97; 40 CFR 52.1241;40 CFR 52.38

The Permittee shall comply with all applicable requirements of 40 CFR pt. 97 forTransport Rule (TR) SO2 Group 2 Units and a TR SO2 Group 2 Source, describedin 40 CFR Section 97.704.

3.0

CD 40 CFR pt. 97; Minn. R.7007.0800, subp. 2

The Permittee shall submit information to the MPCA that the MPCA deemsnecessary to evaluate the applicable requirements of 40 CFR pt. 97 within 60 daysof the date of a letter requesting such information.

4.0

CD Minn. R. 7007.0400, subp. 3 Upon adoption of a new or amended federal applicable requirement and if there aremore than 3 years remaining in the permit term, the Permittee shall file anapplication for an amendment within nine months of promulgation of the applicablerequirement.

5.0

CD hdr SOURCE-SPECIFIC REQUIREMENTS6.0

CD Minn. R. 7007.0800, subp. 2 Permit Appendices: This permit contains appendices as listed in the permit Table ofContents. The Permittee shall comply with all requirements contained in AppendixB: Phase II Acid Rain Permit Application Renewal, Appendix C: InsignificantActivities and Applicable Requirements, Appendices D and E: ApplicableRequirements for Emergency Engines under the area source for 40 CFR pt. 63,subp. ZZZZ.

7.0

CD 40 CFR 72.6 This source is subject to the U.S. EPA Acid Rain Program codified at 40 CFR pts.72, 73, 75, 77, and 78. Certain Acid Rain Program requirements are included inTables A and/or B of this permit, for MPCA tracking purposes. All other Acid RainProgram requirements are referenced in the Phase II Permit Application attached tothis permit as Appendix B.

8.0

CD Minn. R. 7007.0800, subp. 7 Acid Rain Do Not Exceed Allowances: Emissions from the facility cannot exceedany allowances that the source lawfully holds under federal acid rain regulations,except as allowed by Minn. R. 7007.0800, subp. 7.

9.0

CD 40 CFR 72.9(e); Minn. R.7007.1075

Acid Rain Excess Emissions Requirements; If the unit has excess emissions, thedesignated representative shall submit a proposed offset plan in accordance withthe following below:(1) The Permittee of an affected source that has excess emissions in any calendaryear shall submit a proposed offset plan, as required under 40 CFR pt. 77.(2) The Permittee of an affected source that has excess emissions in any calendaryear shall:(i) Pay without demand the penalty required, and pay upon demand the interest onthat penalty, as required by 40 CFR pt. 77; and(ii) Comply with the terms of an approved offset plan, as required by 40 CFR pt. 77.

10.0

CD 40 CFR 72.9(f); Minn. R.7007.1075

Acid Rain Recordkeeping Requirements: The Permittee shall keep the certificate ofrepresentation, all emissions monitoring information, copies of all reports,compliance certifications and related submissions and all records made or requiredunder the Acid Rain Program on site for a period of 5 years from the date thedocument was created.

11.0

CD 40 CFR 72.9(c); Minn. R.7007.1075

Hold allowances after January 1, 2001, as of the allowance transfer deadline, in theunit's compliance subaccount. Allowances may not be less than the total annualemissions of sulfur dioxide from the previous calendar year from the unit andComply with the applicable Acid Rain emissions limitation for sulfur dioxide.

12.0

CD 40 CFR 72.30(c) Acid Rain Program Application for Reissuance: The Permittee shall submit acomplete Acid Rain permit application for each source with an affected unit at least6 months prior to the expiration of an existing Acid Rain permit governing the unitduring Phase II in accordance with 40 CFR Section 72.21.

13.0




21 Apr, 2015 11:26Page 2 of 15

CD 40 CFR 52.21(b)(1)(i)(a) andMinn. R. 7007.3000

Conversion to Steam Generating Facility: If the owner or operator proposes tomodify this facility to also generate steam either for cogeneration or for combinedcycle electric generation, the facility becomes one of the 28 source categories listedin 40 CFR Section 52.21(b)(1)(i)(a) for which the major source threshold is 100 tonsper year. Such a modification constitutes construction of a new major source andmust comply with the requirements of 40 CFR Section 52.21 prior to commencingconstruction of the modification.

14.0

CD hdr OPERATIONAL REQUIREMENTS15.0

CD 40 CFR pt. 50; Minn. Stat. 116.07,subds. 4a & 9; Minn. R.7007.0100, subps. 7A, 7L & 7M;Minn. R. 7007.0800, subps. 1, 2 &4; Minn. Rs.7009.0100-7009.0080.

The Permittee shall comply with National Primary and Secondary Ambient AirQuality Standards, 40 CFR pt. 50, and the Minnesota Ambient Air QualityStandards, Minn. R. 7009.0010 to 7009.0080. Compliance shall be demonstratedupon written request by the MPCA.

16.0

CD Minn. R. 7011.0020 Circumvention: Do not install or use a device or means that conceals or dilutesemissions, which would otherwise violate a federal or state air pollution control rule,without reducing the total amount of pollutant emitted.

17.0

CD Minn. R. 7007.0800, subp. 2;Minn. R. 7007.0800, subp. 16(J)

Air Pollution Control Equipment: Operate all pollution control equipment wheneverthe corresponding process equipment and emission units are operated. At the timeof permit issuance of Permit No. 059000014-004, the facility does not have any airpollution control equipment.

18.0

CD Minn. R. 7007.0800, subps. 14and 16(J)

Operation and Maintenance Plan: Retain at the stationary source an operation andmaintenance plan for all air pollution control equipment. At a minimum, the O & Mplan shall identify all air pollution control equipment and control practices and shallinclude a preventative maintenance program for the equipment and practices, adescription of (the minimum but not necessarily the only) corrective actions to betaken to restore the equipment and practices to proper operation to meet applicablepermit conditions, a description of the employee training program for properoperation and maintenance of the control equipment and practices, and the recordskept to demonstrate plan implementation. At the time of permit issuance of PermitNo. 059000014-004, the facility does not have any air pollution control equipment.

19.0

CD Minn. R. 7019.1000, subp. 4 Operation Changes: In any shutdown, breakdown, or deviation the Permittee shallimmediately take all practical steps to modify operations to reduce the emission ofany regulated air pollutant. The Commissioner may require feasible and practicalmodifications in the operation to reduce emissions of air pollutants. No emissionsunits that have an unreasonable shutdown or breakdown frequency of process orcontrol equipment shall be permitted to operate.

20.0

CD Minn. R. 7011.0150 Fugitive Emissions: Do not cause or permit the handling, use, transporting, orstorage of any material in a manner which may allow avoidable amounts ofparticulate matter to become airborne. Comply with all other requirements listed inMinn. R. 7011.0150.

21.0

CD Minn. Rs. 7030.0010 - 7030.0080 Noise: The Permittee shall comply with the noise standards set forth in Minn. R.7030.0010 to 7030.0080 at all times during the operation of any emission units.This is a state only requirement and is not enforceable by the EPA Administrator orcitizens under the Clean Air Act.

22.0

CD Minn. R. 7007.0800, subp. 9(A) Inspections: The Permittee shall comply with the inspection procedures andrequirements as found in Minn. R. 7007.0800, subp. 9(A).

23.0

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

24.0

CD hdr MONITORING25.0

CD Minn. R. 7007.0800, subp. 4(D) Monitoring Equipment Calibration - The Permittee shall either:

1. Calibrate or replace required monitoring equipment every 12 months; or2. Calibrate at the frequency stated in the manufacturer's specifications.

For each monitor, the Permittee shall maintain a record of all calibrations, includingthe date conducted, and any corrective action that resulted. The Permittee shallinclude the calibration frequencies, procedures, and manufacturer's specifications(if applicable) in the Operations and Maintenance Plan. Any requirements applyingto continuous emission monitors are listed separately in this permit.

26.0




21 Apr, 2015 11:26Page 3 of 15

CD Minn. R. 7007.0800, subp. 4(D) Operation of Monitoring Equipment: Unless otherwise noted in Tables A, and Bmonitoring a process or control equipment connected to that process is notnecessary during periods when the process is shutdown, or during checks of themonitoring systems, such as calibration checks and zero and span adjustments. Ifmonitoring records are required, they should reflect any such periods of processshutdown or checks of the monitoring system.

27.0

CD hdr PERFORMANCE TESTING28.0

CD Minn. R. ch. 7017 Performance Testing: Conduct all performance tests in accordance with Minn. R.ch. 7017 unless otherwise noted in Tables A, and B.

29.0

CD Minn. Rs. 7017.2030, subps. 1-4,7017.2018, 7017.2035, subps. 1-2

Performance Test Notifications and Submittals:

Performance Tests are due as outlined in Tables A and B of the permit. See TableB for additional testing requirements.

Performance Test Notification (written): due 30 days before each Performance TestPerformance Test Plan: due 30 days before each Performance TestPerformance Test Pre-test Meeting: due 7 days before each Performance TestPerformance Test Report: due 45 days after each Performance TestPerformance Test Report - Microfiche Copy: due 105 days after each PerformanceTest

The Notification, Test Plan, and Test Report may be submitted in alternative formatas allowed by Minn. R. 7017.2018.

30.0

CD Minn. R. 7017.2025, subp. 3 Limits set as a result of a performance test (conducted before or after permitissuance) apply until superseded as stated in the MPCA's Notice of Complianceletter granting preliminary approval. Preliminary approval is based on formal reviewof a subsequent performance test on the same unit as specified by Minn. R.7017.2025, subp. 3. The limit is final upon issuance of a permit amendmentincorporating the change.

31.0

CD hdr RECORDKEEPING32.0

CD Minn. R. 7007.0800, subp. 5(C) Recordkeeping: Retain all records at the stationary source or at Great River Energyheadquarters, 12300 Elm Creek Blvd., Maple Grove, Minnesota, 55369, for aperiod of five (5) years from the date of monitoring, sample, measurement, orreport. Records which must be retained at this location include all calibration andmaintenance records, all original recordings for continuous monitoringinstrumentation, and copies of all reports required by the permit. Records mustconform to the requirements listed in Minn. R. 7007.0800, subp. 5(A).

33.0

CD Minn. R. 7007. 0800, subp. 5(B) Recordkeeping: Maintain records describing any insignificant modifications (asrequired by Minn. R. 7007.1250, subp. 3) or changes contravening permit terms (asrequired by Minn. R. 7007.1350, subp. 2), including records of the emissionsresulting from those changes.

34.0

CD Minn. R. 7007.1200, subp. 4 If the Permittee determines that no permit amendment or notification is requiredprior to making a change, the Permittee must retain records of all calculationsrequired under Minn. R. 7007.1200. These records shall be kept for a period of fiveyears from the date the change was made or until permit reissuance, whichever islonger. The records shall be kept at the stationary source for the current calendaryear of operation and may be kept at the stationary source or office of thestationary source for all other years. The records may be maintained in eitherelectronic or paper format.

35.0

CD hdr REPORTING/SUBMITTALS36.0

CD Minn. R. 7019.1000, subp. 3 Shutdown Notifications: Notify the Commissioner at least 24 hours in advance of aplanned shutdown of any control equipment or process equipment if the shutdownwould cause any increase in the emissions of any regulated air pollutant. If theowner or operator does not have advance knowledge of the shutdown, notificationshall be made to the Commissioner as soon as possible after the shutdown.However, notification is not required in the circumstances outlined in Items A, Band C of Minn. R. 7019.1000, subp. 3.

At the time of notification, the owner or operator shall inform the Commissioner ofthe cause of the shutdown and the estimated duration. The owner or operator shallnotify the Commissioner when the shutdown is over.

37.0




21 Apr, 2015 11:26Page 4 of 15

CD Minn. R. 7019.1000, subp. 2 Breakdown Notifications: Notify the Commissioner within 24 hours of a breakdownof more than one hour duration of any control equipment or process equipment ifthe breakdown causes any increase in the emissions of any regulated air pollutant.The 24-hour time period starts when the breakdown was discovered or reasonablyshould have been discovered by the owner or operator. However, notification is notrequired in the circumstances outlined in Items A, B and C of Minn. R. 7019.1000,subp. 2.

At the time of notification or as soon as possible thereafter, the owner or operatorshall inform the Commissioner of the cause of the breakdown and the estimatedduration. The owner or operator shall notify the Commissioner when thebreakdown is over.

38.0

CD Minn. R. 7019.1000, subp. 1 Notification of Deviations Endangering Human Health or the Environment: As soonas possible after discovery, notify the Commissioner or the state duty officer, eitherorally or by facsimile, of any deviation from permit conditions which could endangerhuman health or the environment.

39.0

CD Minn. R. 7019.1000, subp. 1 Notification of Deviations Endangering Human Health or the Environment Report:Within 2 working days of discovery, notify the Commissioner in writing of anydeviation from permit conditions which could endanger human health or theenvironment. Include the following information in this written description:1. the cause of the deviation;2. the exact dates of the period of the deviation, if the deviation has been corrected;3. whether or not the deviation has been corrected;4. the anticipated time by which the deviation is expected to be corrected, if not yetcorrected; and5. steps taken or planned to reduce, eliminate, and prevent reoccurrence of thedeviation.

40.0

S/A Minn. R. 7007.0800, subp. 6(A)(2) Semiannual Deviations Report: due 30 days after end of each calendar half-yearfollowing Permit Issuance. The first semiannual report submitted by the Permitteeshall cover the calendar half-year in which the permit is issued. The first report ofeach calendar year covers January 1 - June 30. The second report of eachcalendar year covers July 1 - December 31. If no deviations have occurred, thePermittee shall submit the report stating no deviations.

41.0

CD Minn. Rs. 7007.1150 - 7007.1500;Minn. R. 7007.0400, subp. 3

Application for Permit Amendment: If a permit amendment is needed, submit anapplication in accordance with the requirements of Minn. R. 7007.1150 throughMinn. R. 7007.1500. Submittal dates vary, depending on the type of amendmentneeded.

Upon adoption of a new or amended federal applicable requirement, and if thereare more than 3 years remaining in the permit term, the Permittee shall file anapplication for an amendment within nine months of promulgation of the applicablerequirement, pursuant to Minn. R. 7007.0400, subp. 3.

42.0

S/A Minn. R. 7007.0400, subp. 2 Application for Permit Reissuance: due 180 days before expiration of ExistingPermit

43.0

CD Minn. R. 7007.1400, subp. 1(H) Extension Requests: The Permittee may apply for an Administrative Amendment toextend a deadline in a permit by no more than 120 days, provided the proposeddeadline extension meets the requirements of Minn. R. 7007.1400, subp. 1(H).Performance testing deadlines from the General Provisions of 40 CFR pt. 60 andpt. 63 are examples of deadlines for which the MPCA does not have authority togrant extensions and therefore do not meet the requirements of Minn. R.7007.1400, subp. 1(H).

44.0

S/A Minn. R. 7007.0800, subp. 6(C) Compliance Certification: due 31 days after end of each calendar year followingPermit Issuance (for the previous calendar year). Submit the certification to theCommissioner on a form approved by the Commissioner. This report covers alldeviations experienced during the calendar year.

45.0

CD Minn. R. 7019.3000 - 7019.3100 Emission Inventory Report: due on or before April 1 of each calendar year followingpermit issuance. The Permittee shall submit this on a form approved by theCommissioner.

46.0

CD Minn. R. 7002.0005 - 7002.0095 Emission Fees: due 30 days after receipt of an MPCA bill.47.0




21 Apr, 2015 11:26Page 5 of 15

S/A 40 CFR 60.7; 40 CFR 75.64; 40CFR 60.4395; Minn. R.7017.1110, subps. 1 & 2

Excess Emissions/Downtime Reports (EER's): due 30 days after end of eachcalendar quarter following Permit Issuance. Submit Deviations Reporting FormDRF-1 as amended. The EER must contain all of the information requested in 40CFR Section 60.7(c). The EER shall indicate all periods of monitor bypass and allperiods of exceedances of a limit including exceedances allowed by an applicablestandard, i.e. during start-up, shutdown, and malfunctions. The EER must besubmitted even if there were no excess emissions, downtime or bypasses duringthe quarter.

48.0




21 Apr, 2015 11:26Page 6 of 15

Subject Item: GP 001 NOX Limit

Associated Items: EU 001 Combustion Turbine 001

EU 002 Turbine 002

NC/CA


CD hdr EMISSION LIMITS1.0

LIMIT Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000

Nitrogen Oxides: less than or equal to 244.0 tons/year using 12-month Rolling Sumfrom the two turbines combined.

This limit applies continuously under all conditions including startup, shutdown, andmalfunction.

2.0

CD hdr RECORDKEEPING REQUIREMENTS3.0

CD Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000; Minn. R. 7007.0800,subps. 4 and 5

By the 15th day of each month, the Permittee shall calculate and record the NOxemissions from the previous month and the previous 12 months, as follows:

NOxmo = NOx001 + NOx002

NOxmo = the NOx emissions from the previous calendar month

NOx12mo = the 12-month rolling sum of the NOxmo values calculated for theprevious 12 calendar months

Where:NOx001 = NOx emissions from EU 001 for the previous month, calculated asdescribed under Subject Item EU 001 of this permit

NOx002 = NOx emissions from EU 002 for the previous month, calculated asdescribed under Subject Item EU 002 of this permit

4.0




21 Apr, 2015 11:26Page 7 of 15

Subject Item: GP 002 Continuous Emission Monitors - EU002

Associated Items: MR 001 NOX monitor

MR 002 O2 monitor

NC/CA


CD Minn. R. 7007.0800, subp. 2 CEMS REQUIREMENTS

The following table is a list of emission units and associated CEMS:

EU 002/SV 002: MR 001 (NOx) and MR 002 (O2)

1.0

CD 40 CFR 75.10(d)(1); 40 CFR60.13(e)(2)

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

2.0

CD 40 CFR 75.10(d)(1) Monitoring Data: Hourly averages shall be computed using at least one data pointin each fifteen minute quadrant of an hour, where the unit combusted fuel duringthat quadrant of an hour. Not withstanding this requirement, an hourly average maybe computed from at least two data points separated by a minimum of 15 minutes(where the unit operates for more than one quadrant of an hour) if data isunavailable as a result of the performance of calibration, quality assurance, orpreventive maintenance activities pursuant to 40 CFR Section 75.21 and appendixB of Part 75, or backups of data from the data acquisition and handling system, orrecertification, pursuant to 40 CFR Section 75.20. The owner or operator shall useall valid measurements or data points collected during an hour to calculate thehourly averages. All data points collected during an hour shall be, to the extentpracticable, evenly spaced over the hour.

3.0

CD 40 CFR 60.13(e); Minn. R.7017.1090

Continuous Operation: CEMS must be operated and data recorded during allperiods of emission unit operation including periods of emission unit start-up,shutdown, or malfunction except for periods of acceptable monitor downtime. Thisrequirement applies whether or not a numerical emission limit applies during theseperiods. A CEMS must not be bypassed except in emergencies where failure tobypass would endanger human health, safety, or plant equipment. Acceptablemonitor downtime includes reasonable periods as listed in Items A, B, C and D ofMinn. R. 7017.1090, subp. 2.

4.0

CD 40 CFR 75.21 CEMS QA/QC: The Permittee of an affected facility shall operate, calibrate, andmaintain each CEMS according to the QA/QC procedures in 40 CFR pt. 75,appendix B as amended.

5.0

CD 40 CFR pt. 75, Appendix B,Section 2.1.1

Daily Calibration Error (CE) Test: The Permittee shall conduct daily CE testing onall CEMS required by the Acid Rain Program, in accordance with 40 CFR pt. 75,Appendix B.

6.0

CD 40 CFR pt. 75, Appendix B,Section 2.2.1 & Section 2.2.2;Minn. R. 7017.1020

Linearity and Leak Check Test (Acid Rain Program): due before end of each QAoperating quarter (as defined in Section 72.) in accordance with procedures in 40CFR pt. 75, Appendix B, Section 2.2.1 and Appendix A, Section 6.2.

7.0

CD Minn. R. 7017.1180, subp. 4 Linearity Test Results Summary: due 30 days after end of each calendar quarterfollowing Linearity and Leak Check Test if performed.

8.0

CD 40 CFR pt. 75, Appendix B,section 2.3.1; Minn. R. 7017.1020

CEMS Relative Accuracy Test Audit (RATA): due before end of each calendarhalf-year following CEM Certification Test, i.e., once every two successive QAoperating quarters (calendar quarter in which there are at least 168 unit operatinghours). Conduct a RATA on all CEMS required by the Acid Rain Program, inaccordance with 40 CFR pt. 75, Appendix B. Relative accuracy test audits may beperformed annually (i.e., once every four successive QA operating quarters, ratherthan once every two successive QA operating quarters) if any of the conditionslisted in 40 CFR pt. 75, Appendix B, Section 2.3.1.2(a) through Section 2.3.1.2(i)are met.

9.0

CD Minn. R. 7017.1180, subp. 2 Relative Accuracy Test Audit (RATA) Notification: due 30 days before CEMSRelative Accuracy Test Audit (RATA)).

10.0

CD Minn. R. 7017.1180, subp. 3 Relative Accuracy Test Audit (RATA) Results Summary: due 30 days after end ofeach calendar quarter in which the CEMS RATA was conducted.

11.0

CD 40 CFR 75.64 Quarterly Reports: Electronically report the data and information in 40 CFR Section75.64 (a), (b), and (c) to the Administrator quarterly.

12.0

CD 40 CFR 75.57; 40 CFR 60.7(f);Minn. R. 7017.1130

Recordkeeping: The Permittee shall retain records of all CEMS monitoring data andsupport information for a period of five years from the date of the monitoringsample, measurement or report. Records shall be kept at the source.

13.0




21 Apr, 2015 11:26Page 8 of 15

CD 40 CFR 60.4345(b) and CFR 4060.13(e)(2)

During each full unit operating hour, both the NOX monitor and the diluent monitormust complete a minimum of one cycle of operation (sampling, analyzing, and datarecording) for each 15-minute quadrant of the hour, to validate the hour. For partialunit operating hours, at least one valid data point must be obtained with eachmonitor for each quadrant of the hour in which the unit operates. For unit operatinghours in which required quality assurance and maintenance activities areperformed on the CEMS, a minimum of two valid data points (one in each of twoquadrants) are required for each monitor to validate the NOX emission rate for thehour.

14.0




21 Apr, 2015 11:26Page 9 of 15

Subject Item: EU 001 Combustion Turbine 001

Associated Items: GP 001 NOX Limit

SV 001 Combustion Turbine

NC/CA


CD hdr EMISSION AND OPERATING LIMITS1.0

LIMIT Minn. R. 7011.2300, subp. 1 Opacity: less than or equal to 20 percent opacity once operating temperatures havebeen attained.

2.0

LIMIT Minn. R. 7011.2300, subp. 2 Sulfur Dioxide: less than or equal to 0.50 lbs/million Btu heat input using 3-hourRolling Average (compliance with the fuel sulfur content of 40 CFR Section80.510(c) will demonstrate compliance with this requirement.)

3.0

CD Minn. R. 7005.0100, subp. 35a Permitted Fuel type: Pipeline natural gas or No. 2 fuel oil/diesel fuel meeting therequirements of 40 CFR Section 80.510(c) only by design.

4.0

CD hdr MONITORING AND RECORDKEEPING REQUIREMENTS5.0


By the 15th day of each month, the Permittee shall calculate and record the NOxemissions from the previous month (NOx001) using the procedures outlined inScenario 1, 2, or 3, below as applicable.

6.0

CD 40 CFR 75.19; Minn. R.7007.0800, subps. 4 and 5

The Permittee shall use the fuel flow meter as described under 40 CFR Section75.19 low mass emission methodology to track fuel use and calculate NOx andSO2 emissions for CSAPR allowances.

7.0

CD Minn. R. 7007.0800, subp. 11 Operating Scenarios - The Permittee shall select and adhere to one of the followingoperating scenarios (Scenario 1, 2, or 3) for EU 001. The selection of the scenarioshall be documented as a permanent written record and shall include the date ofimplementation. The Permittee may change from Scenario 1 to Scenario 2 or 3, orfrom Scenario 2 to Scenario 3. The Permittee is prohibited from changing fromScenario 3 to Scenario 1 or 2, or from Scenario 2 to Scenario 1. If the Permitteechanges the operating scenario, the record shall be amended to reflect the changeand the date of change. A change in operating scenario may only occur on the firstday of a calendar month.

8.0

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

Calculations and Recordkeeping During Change of Operating Scenario:

If the Permittee changes from Scenario 1 or 2 to Scenario 3, NOx CEMS data shallbe used to calculate the monthly NOx emissions starting on the first day of the nextcalendar month following CEMS certification testing.

If the Permittee changes from Scenario 1 to Scenario 2, NOx emission curve datashall be used to calculate monthly NOx emissions starting on the first day of thenext calendar month following approval of the NOx testing. Upon receipt ofapproval letter from the MPCA, the Permittee shall recalculate emissions after themonitoring change and prior to availability of test results.

9.0

CD Minn. R. 7007.0800, subp. 11 OPERATING SCENARIO 1 MONITORING AND CALCULATIONS10.0


Daily Recordkeeping: Each day, the Permittee shall record the amounts of naturalgas and fuel oil combusted in EU 001.

11.0


Monthly Recordkeeping: By the 15th day of each month, the Permittee shallcalculate and record the amounts of natural gas and fuel oil combusted during theprevious calendar month.

12.0




21 Apr, 2015 11:26Page 10 of 15

CD Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000

By the 15th day of each month, calculate and record the NOx emissions using thefollowing equation:

NOx001 = NOXfo1 + NOXng1

where:NOXfo1 = NOX from fuel oil combustion in EU 001, in tonsNOXng1 = NOX from natural gas combustion in EU 001, in tonsNOXfo1 = (EFfo1 x Qfo1 x 0.137)/2000NOXng1 = (EFng1 x Qng1 x NGhc)/2000

EFfo1 = the current site-specific or most current AP-42 and 40 CFR Section 75.19NOx emission factor for uncontrolled fuel oil combustion in a turbine, in lb/MMBtuheat input (current AP-42 factor is 0.88 lb/MMBtu heat input)(continued below)

13.0


(continued from above)where:EFng1 = the current site-specific or AP-42 and 40 CFR Section 75.19 NOxemission factor for uncontrolled turbine firing natural gas (unless the Permitteechooses lean pre-mix or water injection, in which it is the appropriate factor for thattechnology), in lb/MMBtu heat input (current AP-42 factor for uncontrolled firing is0.32 lb/MMBtu heat input)

Qfo1 = the quantity of fuel oil combusted in EU 001 during the previous month, ingallons

Qng1 = the quantity of natural gas combusted in EU 001 during the previousmonth, in million cubic feet

0.137 = fuel oil heating value conversion factor (137 MMBtu/1000 gal)

NGhc = natural gas heating value, in MMBtu/million cubic feet (1050, or valuecalculated from hourly fuel usage and hourly heat input determined for EU 002)

14.0


CD Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000; Minn. R. 7017.2020,subp. 1

Initial Performance Test: to be completed prior to implementation of OperatingScenario 2, to measure NOx emissions for developing a NOx emissions curve fornatural gas and fuel oil.

NOx emissions shall be measured at a minimum of 4 equally spaced operatingloads ranging from minimum to maximum operating load, using US EPA Method 20in 40 CFR Part 60, Appendix A. Test results shall be used to develop a NOxemissions curve based on operating load (lb NOx/hr vs. gross megawatt-hours).Separate curves shall be developed for each fuel (oil and gas) and for eachoperating season (summer and winter). As an alternative, the Permittee maychoose to use the NOx Emissions Estimation Protocol for Gas-Fired Peaking Unitsand Oil-Fired Peaking Units, from 40 CFR Part 75, Appendix E.

Additional requirements related to performance testing are found under SubjectItem Total Facility. The Permittee shall submit a copy of each NOx emission curvealong with the required test report.

16.0

S/A Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000; Minn. R. 7017.2020,subp. 1

Performance Test: due before end of each 60 months following Initial PerformanceTest or after each 3000 hours of operation after implementation of OperatingScenario 2, whichever timeframe is shorter, to measure NOx emissions andredevelop NOx emissions curves as described for the Initial Performance Test.

17.0


Hourly Recordkeeping and Calculations: for each hour of operation, the Permitteeshall record the total gross megawatt-hours of electricity produced, and the type offuel combusted. The Permittee shall calculate and record the hourly NOxemissions rate in lb/hr based on the emissions curve developed from test data.

18.0


Monthly Recordkeeping and Calculations: By the 15th day of each month, thePermittee shall calculate and record the NOx emission from the previous calendarmonth (NOx001) by summing the hourly NOx emission rates for the month.

19.0





21 Apr, 2015 11:26Page 11 of 15

CD Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000; Minn. R. 7007.0800,subp. 5

NOx Monitoring: The Permittee shall install, calibrate, maintain, and operate acontinuous emission monitoring system (CEMS) for NOx and oxygen, and shallrecord the output of the system when combusting any fuel. The system shall at aminimum calculate NOx emissions on an hourly lb/MMBtu basis for conversion tolb/hour emissions based on hourly fuel usage.

A flowmeter shall be installed to determine hourly fuel usage and the hourly heatinput.

21.0


Hourly Fuel Usage Recordkeeping: The Permittee shall calculate and record thehourly fuel usage in gallons/hour (gph) of fuel oil and cubic feet per hour (cfh) ofnatural gas.

22.0


Monthly Recordkeeping and Calculations: By the 15th day of each month, thePermittee shall calculate and record the monthly NOx emissions (NOx001), in tons,using the hourly CEMS and fuel usage data.

23.0

CD hdr MONITORING REQUIREMENTS FOR CMS24.0

CD Minn. R. 7007.0800, subp. 4 The Permittee shall calibrate, operate and maintain a continuous monitoring system(CMS) for the fuel flow monitor consistent with 40 CFR Section 75.19.

25.0

CD Minn. R. 7007.0800, subp. 4 CMS QA/QC: The Permittee shall follow the manufacturer recommendation forpreventative maintenance and periodic monitoring to ensure CMS reliabilityincluding but not limited to annual calibrations for the fuel flow monitor.

26.0




21 Apr, 2015 11:26Page 12 of 15

Subject Item: EU 002 Turbine 002

Associated Items: GP 001 NOX Limit

MR 001 NOX monitor

MR 002 O2 monitor

SV 002 Turbine 002 Exhaust

NC/CA



LIMIT 40 CFR 60.4320(a) and 40 CFRpt. 60, subp. KKKK, Table 1

Nitrogen Oxides: less than or equal to 15 parts per million at 15 percent O2 or 54ng/J of useful output (0.43 lb/MWh) when turbine is operating at or above 75percent of peak load and when operating at 0°F or above.

2.0

LIMIT 40 CFR 60.4320(a) and 40 CFRpt. 60, subp. KKKK, Table 1

Nitrogen Oxides: less than or equal to 96 parts per million at 15 percent O2 or 590ng/J of useful output (4.70 lb/MWh) when turbine is operating at less than 75percent of peak load or operating at temperatures less than 0°F.

3.0

LIMIT 40 CFR 60.4330(a) Sulfur Dioxide: less than or equal to 110 nanograms/joule heat input (0.90 lb/MWh)gross output or the Permittee must not burn any fuel in EU 002 which contains totalpotential sulfur emissions in excess of 26 ng SO2/J (0.060 lb SO2/MMBtu) heatinput.

4.0

LIMIT Minn. R. 7011.2300, subp. 2 Sulfur Dioxide: less than or equal to 0.50 lbs/million Btu heat input using 3-hourRolling Average (compliance with 40 CFR Section 60.4330(a) will demonstratecompliance with this requirement.)

5.0

LIMIT Minn. R. 7011.2300, subp. 1 Opacity: less than or equal to 20 percent opacity once operating temperatures havebeen attained. Operating temperatures are attained after completion of startup andcontinue until a shutdown or malfunction occurs.

6.0

CD hdr OPERATING REQUIREMENTS7.0

CD Minn. R. 7007.0800, subp. 2 Permitted Fuel Type: Pipeline natural gas by design.8.0


Startup shall be completed no later than 45 minutes after the start of fuelcombustion.

9.0

CD 40 CFR 60.8(c) Operations during periods of startup, shutdown, and malfunction shall not constituterepresentative conditions for the purpose of a performance test nor shall emissionsin excess of the level of the applicable emission limit during periods of startup,shutdown, and malfunction be considered a violation of the applicable emissionlimit unless otherwise specified in the applicable standards.

10.0

CD 40 CFR 60.4333(a) The Permittee must operate and maintain EU 002, air pollution control equipment,and monitoring equipment in a manner consistent with good air pollution controlpractices for minimizing emissions at all times including startup, shutdown, andmalfunction.

11.0



Each time EU 002 is operated, monitor and record the amount of time it is operatedin "startup" mode. The Permittee shall maintain a log showing the length of thestartup time for each operating event.

13.0

CD Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000; 40 CFR 60.4340(b);Minn. R. 7011.2350; Minn. R.7017.1006

NOx Monitoring: The Permittee shall use a CEMS to measure NOx emissions forSV 002 being monitored. The NOx CEMS shall be operated and maintained inaccordance with 40 CFR pt. 75, Appendix B and 40 CFR Section 60.4340(b)(1).Additional monitoring requirements are also located at GP 002 Level.

A flowmeter shall be installed to determine hourly fuel usage and the hourly heatinput.

The system shall at a minimum calculate NOx emissions on an hourly lb/MMBtubasis for conversion to lb/hr NOx emissions based on hourly fuel usage.

14.0




21 Apr, 2015 11:26Page 13 of 15


Hourly Fuel Usage Recordkeeping: The Permittee shall calculate and record thehourly fuel usage in cubic feet per hour (cfh) of natural gas.

15.0

CD Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000; 40 CFR 60.4350;Minn. R. 7007.0800, subps. 4 and5

Monthly Recordkeeping and Calculations: By the 15th day of each month, thePermittee shall calculate and record the monthly NOx emissions (NOx002), in tons,using the hourly CEMS and fuel usage data.

16.0

CD 40 CFR 75.10 The Permittee shall record, measure and calculate SO2, NOx, and CO2 emissionrates for EU 002 in accordance with 40 CFR pt. 75.

17.0

CD 40 CFR 60.4365(a); Minn. R.7007.0800, subp. 4

Fuel Monitoring: The Permittee must use a current, valid purchase contract, tariffsheet or transportation contract specifying that the total sulfur content for naturalgas is 20 grains of sulfur or less per 100 standard cubic feet to demonstrate thatthe potential sulfur emissions of the fuel combusted in the turbine do not exceed 26ng SO2/J (0.060 lb SO2/MMBtu) heat input.

18.0




21 Apr, 2015 11:26Page 14 of 15

Subject Item: EU 003 Emergency Diesel Fire Pump Engine

NC/CA



LIMIT Minn. R. 7011.2300, subp. 2 Sulfur Dioxide: less than or equal to 0.50 lbs/million Btu heat input using 3-hourRolling Average (compliance with the fuel sulfur content requirements of 40 CFRSection 80.510(c) will demonstrate compliance with this requirement.)

2.0


3.0

CD hdr OPERATING CONDITIONS4.0

LIMIT Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000; Minn. R. 7007.0800,subp. 5

Operating Hours: less than or equal to 150 hours/year using 12-month Rolling Sumto be calculated by the 28th day of each month.

5.0

CD Minn. R. 7005.0100, subp. 35a Permitted Fuel Restriction: No. 2 fuel oil/diesel fuel meeting the requirements of 40CFR Section 80.510(c) only by design.

6.0


CD Minn. R. 7007.0800, subp. 5 The Permittee shall keep records of fuel type and usage on a monthly basis.8.0


Operating Hours Recordkeeping: Except as described below, the Permittee shallmaintain a record of hours of operation of EU 003 and calculate and record the12-month rolling sum of operating hours by the 28th day of each month.

If operating hours recordkeeping demonstrates that EU 003 operated for no morethan 75 operating hours in the previous calendar year, the Permittee may recordEU 003 operating hours on a calendar year basis. The annual sum must becalculated by April 1 of each year for the previous calendar year.

If any calendar year sum exceeds 75 operating hours, the Permittee shallcommence monthly recordkeeping until records document no more than 75operating hours during each of two consecutive calendar years.

9.0

CD Minn. R. 7007.0800, subp. 2 Additional Requirements for Engine EU 003 are in Appendix D.10.0




21 Apr, 2015 11:26Page 15 of 15

Subject Item: EU 004 Diesel Starting Engine

NC/CA




2.0

LIMIT Minn. R. 7011.2300, subp. 2 Sulfur Dioxide: less than or equal to 0.50 lbs/million Btu heat input (compliance withthe fuel sulfur content with the requirements of 40 CFR Section 80.510(c) willdemonstrate compliance with this requirement.)

3.0

CD hdr OPERATING CONDITIONS4.0

LIMIT Title I Condition: Avoid majorsource under 40 CFR52.21(b)(1)(i) and Minn. R.7007.3000; Minn. R. 7007.0800,subp. 5

Operating Hours: less than or equal to 70 hours/year using 12-month Rolling Sumto be calculated by the 28th day of each month.

5.0

CD Minn. R. 7005.0100, subp. 35a Permitted Fuel Restriction: No. 2 fuel oil/diesel fuel meeting the requirements of 40CFR Section 80.510(c) only by design.

6.0

CD hdr RECORDKEEPING REQUIREMENTS7.0

CD Minn. R. 7007.0800, subp. 5 The Permittee shall keep records of fuel type and usage on a monthly basis.8.0


Operating Hours Recordkeeping: Except as described below, maintain a record ofEU 004 hours of operation and calculate and record the EU 004 12-month rollingsum of operating hours by the 28th day of each month. Hours may be tracked bytracking the number of starts, and assuming an operating time of 15 minutes perstart.

If operating hours recordkeeping demonstrates that EU 004 operated for no morethan 20 operating hours in the previous calendar year, the Permittee may recordEU 004 operating hours on a calendar year basis. The annual sum must becalculated by April 1 of each year for the previous calendar year.

If any calendar year sum exceeds 20 operating hours, the Permittee shallcommence monthly recordkeeping until records document no more than 20operating hours during each of two consecutive calendar years.

9.0

CD Minn. R. 7007.0800, subp. 2 Additional Requirements for Engine EU 004 are in Appendix D.10.0

Attachment 3- Points Calculator

Points Calculator

1) AQ Facility ID No.: 147C Total Points 02) Facility Name: Great River Energy-Cambridge3) Small business? y/n? N 4) DQ Numbers (including all rolled) : 4275 5) Date of each Application Received: 01/24/20136) Final Permit No. 05900014-0047) Permit Staff Amrill Okonkwo8) "Work completed" in which .xls file (i.e. unit 2b, unit 1a, biofuels)? NA

TotalApplication Type DQ No. Qty. Points Points DetailsAdministrative Amendment 1 0Minor Amendment 4 0Applicability Request 10 0Moderate Amendment 15 0Major Amendment 25 0Individual State Permit (not reissuance) 50 0Individual Part 70 Permit (not reissuance) 75 0

Additional PointsModeling Review 15 0

BACT Review 15 0LAER Review 15 0CAIR/Part 75 CEM analysis 10 0NSPS Review 10 0NESHAP Review 10 0Case-by-case MACT Review 20 0Netting 10 0Limits to remain below threshold 10 0Plantwide Applicability Limit (PAL) 20 0AERA review 15 0Variance request under 7000.7000 35 0Confidentiality request under 7000.1300 2 0EAW reviewPart 4410.4300, subparts 18, item A; and 29 15 0Part 4410.4300, subparts 8, items A & B; 10, items A to C; 16, items A & D; 17, items A to C & E to G; and 18, items B & C

35 0

Part 4410.4300, subparts 4; 5 items A & B; 13; 15; 16, items B & C; and 17 item D

70 0

Add'l Points 0NOTES: This permit is a reissuance; therefore no additional points are required for this reissuance.

(DQ DQ 4275)

Documents

TECHNICAL SUPPORT DOCUMENT For DRAFT/PROPOSED AIR … · Great River Energy‐ Cambridge was subject to CAIR when initially promulgated in 2005. Great River Energy‐ Cambridge submitted