Permit Notice to the Permittee Permit Shield Facility ... · Total Facility Operating Permit...

Permit Applications Table

Permit Type Application Date Permit Action

Total Facility Operating Permit –Reissuance 12/10/2012 003

TABLE OF CONTENTS

Notice to the Permittee Permit Shield Facility Description

Table A: Limits and Other Requirements Table B: Submittals

Appendices

Appendix I: Insignificant Activities and Applicable Requirements

Appendix II: Applicable Requirements for Black Start Engine under the area source for 40 CFR pt. 63, subp. ZZZZ

Appendix III: Applicable Requirements for Rock Lake Telecom Emergency Generator under the area source for 40 CFR pt. 63, subp. ZZZZ

NOTICE TO THE PERMITTEE: Your stationary source may be subject to the requirements of the Minnesota Pollution Control Agency’s (MPCA) solid waste, hazardous waste, and water quality programs. If you wish to obtain information on these programs, including information on obtaining any required permits, please contact the MPCA general information number at: Metro Area 651‐296‐6300 Outside Metro Area 1‐800‐657‐3864 TTY 651‐282‐5332 The rules governing these programs are contained in Minn. R. chs. 7000‐7105. Written questions may be sent to: Minnesota Pollution Control Agency, 520 Lafayette Road North, St. Paul, Minnesota 55155‐4194. Questions about this air emission permit or about air quality requirements can also be directed to the telephone numbers and address listed above. PERMIT SHIELD: Subject to the limitations in Minn. R. 7007.1800, compliance with the conditions of this permit shall be deemed compliance with the specific provision of the applicable requirement identified in the permit as the basis of each condition. Subject to the limitations of Minn. R. 7007.1800 and 7017.0100, subp. 2, notwithstanding the conditions of this permit specifying compliance practices for applicable requirements, any person (including the Permittee) may also use other credible evidence to establish compliance or noncompliance with applicable requirements. FACILITY DESCRIPTION: Great River Energy‐ Rock Lake operates a single simple‐cycle 29.3‐megawatt GE Combustion Turbine. In addition, there are the following insignificant activities: one black start diesel engine, Telecom building LP emergency generator, 200,000‐gallon aboveground No. 2 fuel oil storage tank and associated fuel oil piping, and unpaved roads.

TABLE A: LIMITS AND OTHER REQUIREMENTSGreat River Energy - Rock Lake

11500011 - 003

Facility Name:

Permit Number:

07/07/15A-1

Table A contains limits and other requirements with which your facility must comply. The limits are located in the first column ofthe table (What To do). The limits can be emission limits or operational limits. This column also contains the actions that you musttake and the records you must keep to show that you are complying with the limits. The second column of Table A (Why to do it)lists the regulatory basis for these limits. Appendices included as conditions of your permit are listed in Table A under total facilityrequirements.

Subject Item: Total Facility

What to do Why to do it

FACILITY SUBJECT TO TRANSPORT RULE(TR) /CROSS-STATE AIRPOLLUTION RULE (CSAPR)

hdr

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.

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) SO2 Group 2 Units and a TR SO2 Group 2 Source, describedin 40 CFR Section 97.704.

40 CFR pt. 97; 40 CFR 52.1241; 40 CFR 52.39

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.

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

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 for CSAPR.

Minn. R. 7007.0400, subp. 3

DETERMINING IF A PROJECT/MODIFICATION IS SUBJECT TO NEW SOURCEREVIEW

hdr

These requirements apply where there is a reasonable possibility (as defined in 40CFR Section 52.21(r)(6)(vi)) that a proposed project, analyzed using theactual-to-projected-actual (ATPA) test (either by itself or as part of the hybrid testdescribed in 40 CFR Section 52.21(a)(2)(iv)(f)) and found to not be part of a majormodification, may result in a significant emissions increase. If the ATPA test is notused for a particular project, or if there is not a reasonable possibility that theproposed project could result in a significant emissions increase, then theserequirements do not apply to that project.

Even though a particular modification is not subject to New Source Review, apermit amendment, recordkeeping, or notification may still be required under Minn.R. 7007.1150 - 7007.1500.

Title I Condition: 40 CFR Section 52.21(r)(6); Minn. R.7007.3000; Minn. R. 7007.0800, subp. 2

Preconstruction Documentation -- Before beginning actual construction on aproject, the Permittee shall document the following:

1. Project description2. Identification of any emission unit (EU) whose emissions of an NSR pollutantcould be affected3. Pre-change potential emissions of any affected existing EU, and the projectedpost-change potential emissions of any affected existing or new EU.4. A description of the applicability test used to determine that the project is not amajor modification for any regulated NSR pollutant, including the baseline actualemissions, the projected actual emissions, the amount of emissions excluded dueto increases not associated with the modification and that the EU could haveaccommodated during the baseline period, an explanation of why the amountswere excluded, and any creditable contemporaneous increases and decreases thatwere considered in the determination.

The Permittee shall maintain records of this documentation.

Title I Condition: 40 CFR Section 52.21(r)(6); Minn. R.7007.3000; Minn. R. 7007.1200, subp. 4; Minn. R.7007.0800, subps. 4 & 5

The Permittee shall monitor the actual emissions of any regulated NSR pollutantthat could increase as a result of the project and that were analyzed using theATPA test, and the potential emissions of any regulated NSR pollutant that couldincrease as a result of the project and that were analyzed using potential emissionsin the hybrid test. The Permittee shall calculate and maintain a record of the sum ofthe actual and potential (if the hybrid test was used in the analysis) emissions ofthe regulated pollutant, in tons per year on a calendar year basis, for a period of 5years following resumption of regular operations after the change, or for a period of10 years following resumption of regular operations after the change if the projectincreases the design capacity of or potential to emit of any unit associated with theproject.

Title I Condition: 40 CFR Section 52.21(r)(6); Minn. R.7007.3000; Minn. R. 7007.0800, subps. 4 & 5


11500011 - 003

Facility Name:

Permit Number:

07/07/15A-2

The Permittee must submit a report to the Agency if the annual summed (actual,plus potential if used in hybrid test) emissions differ from the preconstructionprojection and exceed the baseline actual emissions by a significant amount aslisted at 40 CFR Section 52.21(b)(23). Such report shall be submitted to theAgency within 60 days after the end of the year in which the exceedances occur.The report shall contain:

a. The name and ID number of the facility, and the name and telephone number ofthe facility contact personb. The annual emissions (actual, plus potential if any part of the project wasanalyzed using the hybrid test) for each pollutant for which the preconstructionprojection and significant emissions increase are exceeded.c. Any other information, such as an explanation as to why the summed emissionsdiffer from the preconstruction projection.

Title I Condition: 40 CFR Section 52.21(r)(6); Minn. R.7007.3000; Minn. R. 7007.0800, subps. 4 & 5

OPERATIONAL REQUIREMENTS hdr

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.

40 CFR pt. 50; Minn. Stat. Section 116.07, subds. 4a &9; Minn. R. 7007.0100, subps. 7A, 7L & 7M; Minn. R.7007.0800, subps. 1, 2 & 4; Minn. R.7009.0010-7009.0080

Permit Appendices: This permit contains appendices as listed in the permit Table ofContents. The Permittee shall comply with all requirements contained in theappendices.

Minn. R. 7007.0800 subp. 2

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.

Minn. R. 7011.0020

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. 11500011-003, the facility does not have any airpollution control equipment.

Minn. R. 7007.0800, subp. 2; Minn. R. 7007.0800,subp. 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. 11500011-003, the facility does not have any air pollution control equipment.

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

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.

Minn. R. 7019.1000, subp. 4

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.

Minn. R. 7011.0150

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.

Minn. R. 7030.0010 - 7030.0080

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

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

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

Minn. R. 7007.0800, subp. 16

MONITORING REQUIREMENTS hdr


11500011 - 003

Facility Name:

Permit Number:

07/07/15A-3

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; or3. Calibrate according to 40 CFR pt. 75.

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.

Minn. R. 7007.0800, subp. 4(D)

Operation of Monitoring Equipment: Unless otherwise noted in Tables A and/or 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.

Minn. R. 7007.0800, subp. 4(D)

RECORDKEEPING hdr

Recordkeeping: Retain all records at the Great River Energy headquarters, 12300Elm Creek Boulevard, Maple Grove, Minnesota, 55369 for a period of five (5) yearsfrom the date of monitoring, sample, measurement, or report. Records which mustbe retained at this location include all calibration and maintenance records, alloriginal recordings for continuous monitoring instrumentation, and copies of allreports required by the permit. Records must conform to the requirements listed inMinn. R. 7007.0800, subp. 5(A).

Minn. R. 7007.0800, subp. 5(C)

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.

Minn. R. 7007. 0800, subp. 5(B)

When the Permittee determines that no permit amendment or notification isrequired prior to making a change, the Permittee must retain records of allcalculations required under Minn. R. 7007.1200. These records shall be kept for aperiod of five years from the date the change was made or until permit reissuance,whichever is longer. The records shall be kept at the stationary source for thecurrent calendar year of operation and may be kept at the stationary source oroffice of the stationary source for all other years. The records may be maintained ineither electronic or paper format.

Minn. R. 7007.1200, subp. 4

REPORTING/SUBMITTALS hdr

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, B,and 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.

Minn. R. 7019.1000, subp. 3

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.

Minn. R. 7019.1000, subp. 2

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.

Minn. R. 7019.1000, subp. 1


11500011 - 003

Facility Name:

Permit Number:

07/07/15A-4

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 corrected3. 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.

Minn. R. 7019.1000, subp. 1

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.

Minn. R. 7007.1150 - Minn. R. 7007.1500

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).

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

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.

Minn. R. 7019.3000 - Minn. R. 7019.3010

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


11500011 - 003

Facility Name:

Permit Number:

07/07/15A-5

Subject Item: EU 001 Combustion Turbine - 29.3 MW

Associated Items: SV 001

What to do Why to do it

Opacity: less than or equal to 20 percent opacity once operating temperatures havebeen attained.

Minn. R. 7011.2300, subp. 1

Sulfur Dioxide: less than or equal to 0.50 lbs/million Btu heat input using 3-hourRolling Average . The potential to emit from the unit is 0.051 lb/MMBtu due toequipment design and allowable fuels.

Minn. R. 7011.2300, subp. 2

Fuel type: No. 2 fuel oil/diesel fuel meeting the requirements of 40 CFR Section80.510(c) only by design.

Minn. R. 7005.0100, subp. 35a

Fuel Monthly Recordkeeping: The Permittee shall keep records of fuel type andusage on a monthly basis.

Minn. R. 7007.0800, subp. 5

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

40 CFR pt. 97; 40 CFR 75.19; Minn. R. 7007.0800,subps. 4 and 5

The Permittee shall calibrate, operate and maintain a continuous monitoringsystem (CMS) for the fuel flow monitor consistent with 40 CFR Section 75.19

Minn. R. 7007.0800, subp. 4

CMS QA/QC: The Permittee shall follow the manufacturer recommendation forpreventative maintenance and periodic monitoring to ensure CMS reliability.

Minn. R. 7007.0800, subp. 4

TABLE B: SUBMITTALSFacility Name: Great River Energy - Rock Lake

Permit Number: 11500011 - 003

07/07/15B-1

Also, where required by an applicable rule or permit condition, send to the Permit Document Coordinator notices of:- accumulated insignificant activities,- installation of control equipment,- replacement of an emissions unit, and- changes that contravene a permit term.

Table B lists most of the submittals required by this permit. Please note that some submittal requirements may appear in Table Aor, if applicable, within a compliance schedule located in Table C. Table B is divided into two sections in order to separately listone-time only and recurrent submittal requirements.

Each submittal must be postmarked or received by the date specified in the applicable Table. Those submittals required by parts7007.0100 to 7007.1850 must be certified by a responsible official, defined in Minn. R. 7007.0100, subp. 21. Other submittals shallbe certified as appropriate if certification is required by an applicable rule or permit condition.

Send submittals that are required to be submitted to the U.S. EPA regional office to:

Chief Air Enforcement Air and Radiation Branch EPA Region V 77 West Jackson Boulevard Chicago, Illinois 60604

Send any application for a permit or permit amendment to:

Fiscal Services Minnesota Pollution Control Agency 520 Lafayette Road North St. Paul, Minnesota 55155-4194

Send submittals that are required by the Acid Rain Program to:

U.S. Environmental Protection Agency Clean Air Markets Division 1200 Pennsylvania Avenue NW (6204N) Washington, D.C. 20460

Unless another person is identified in the applicable Table, send all other submittals to:

AQ Compliance Tracking Coordinator Industrial Division Minnesota Pollution Control Agency 520 Lafayette Road North St. Paul, Minnesota 55155-4194

TABLE B: ONE TIME SUBMITTALS OR NOTIFICATIONSFacility Name: Great River Energy - Rock Lake


07/07/15B-2

What to send When to send Portion of Facility Affected

Application for Permit Reissuance due 180 days before expiration of ExistingPermit

Total Facility

TABLE B: RECURRENT SUBMITTALSFacility Name: Great River Energy - Rock Lake


07/07/15B-3

What to send When to send Portion of Facility Affected

Semiannual Deviations Report due 30 days after end of each calendarhalf-year starting 06/09/2008 following permitissuance. The first semiannual reportsubmitted by the Permittee shall cover thecalendar half-year in which the permit isissued. The first report of each calendar yearcovers January 1 - June 30. The secondreport of each calendar year covers July 1 -December 31. If no deviations have occurred,the Permittee shall submit the report statingno deviations.

Total Facility

Compliance Certification due 31 days after end of each calendar yearfollowing Permit Issuance (for the previouscalendar year). The Permittee shall submitthis to the Commissioner on a form approvedby the Commissioner. This report covers alldeviations experienced during the calendaryear.

Total Facility

Facility Name: Great River Energy ‐ Rock Lake Permit Number: 11500011‐003

APPENDIX MATERIAL Facility Name: Great River Energy ‐ Rock Lake Permit Number: 11500011‐003

Appendix I: Insignificant Activities and Applicable Requirements

Under Minn. R. 7007.1250, subp. 1(A), the Permittee may add insignificant activities to the stationary source throughout the term of the permit without obtaining a permit amendment. Certain exclusions apply and are listed in Minn. R. 7007.1250, subp. 2. The following table is a listing of the insignificant activities.

Minn. R. 7007.1300, Rule Description of the Activity General Applicable

Requirement

subp. 3(I) Individual emissions units at a stationary source, each of which have a potential to emit the following pollutants in amounts 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. Great River Energy has the following equipment that qualify under this subpart:

Telecom building LP emergency generator SG020

Minn. R. 7011.0710/0715;

(PM, SO2 & Opacity) Minn. R. 7011.2300 & 40 CFR pt. 63, subp. ZZZZ (SO2 & Opacity)

subp. 3(J) Fugitive Emissions from roads and parking lots.

Facility has unpaved roads and parking lots

Minn. R. 7011.0150

subp. 4 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. Great River Energy has the following equipment that qualify under this subpart

200,000 gals fuel oil storage tank and associated

piping

Diesel Black Start Engine

Minn. R. 7011.0710/0715 Minn. R. 7011.1505 Minn. R. 7011.2300 & 40 CFR pt. 63, subp. ZZZZ (SO2 & Opacity) See Appendix II below


INTENTIONALLY LEFT BLANK


Appendix II: Applicable Requirements for Black Start Engine under the area source for 40 CFR pt. 63, subp. ZZZZ

Requirement Title Citation Requirement

COMPLIANCE DATE 40 CFR Section 63.6595(a); Minn. R. 7011.8150

The Permittee shall comply with the applicable emission and operational limitations from 40 CFR pt. 63, subp. ZZZZ no later than May 3, 2013.

EMISSION OPERATIONAL REQUIREMENTS

Hdr EMISSION AND OPERATIONAL REQUIREMENTS

40 CFR Section 63.6603(a); 40 CFR pt. 63, subp. ZZZZ, Table 2d; Minn. R. 7011.8150

Change oil and filter every 500 hours of operation or annually, whichever comes first. The Permittee has the option of utilizing an oil analysis program in order to extend the oil change requirement as described below.

40 CFR Section 63.6603(a); 40 CFR pt. 63, subp. ZZZZ, Table 2d(4); Minn. R. 7011.8150

Inspect air cleaner every 1,000 hours of operation or annually, whichever comes first and replace as necessary.


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

COMPLIANCE REQUIREMENT

40 CFR Section 63.6605(a); Minn. R. 7011.8150

The Permittee shall be in compliance with the emission limitations and operating limitations in 40 CFR pt. 63, subp. ZZZZ that apply at all times.

40 CFR Section 63.6605(b); Minn. R. 7011.8150

At all times the Permittee shall operate and maintain any affected source, including associated air pollution control equipment and monitoring equipment, in a manner consistent with safety and good air pollution control practices for minimizing emissions. The general duty to minimize emissions does not require the Permittee to make any further efforts to reduce emissions if levels required by this standard have been achieved. Determination of whether such operation and maintenance procedures are being used will be based on information available to the Administrator which may include, but is not limited to, monitoring results, review of operation and maintenance procedures, review of operation and maintenance records, and inspection of the source.

40 CFR Section 63.6625 (e); Minn. R. 7011.8150

The Permittee shall operate and maintain the stationary RICE and after‐treatment control device (if any) according to the manufacturer’s emission‐related written instructions or develop a maintenance plan which must provide to the extent



practicable for the maintenance and operation of the engine in a manner consistent with good air pollution control practice for minimizing emissions.

40 CFR Section 63.6625(f); Minn. R. 7011.8150

The Permittee shall install a non‐resettable hour meter if one is not already installed.

40 CFR Section 63.6625(h); Minn. R. 7011.8150

The Permittee shall minimize the engine’s time spent at idle during startup and minimize the engine’s startup time to a period needed for appropriate and safe loading of the engine, not to exceed 30 minutes, after which time the emission standards applicable to all times other than startup apply.

40 CFR Section 63.6625(i); Minn. R. 7011.8150

The Permittee has the option of utilizing an oil analysis program in order to extend the specified oil change requirement in 40 CFR pt. 63, subp. ZZZZ, Tables 2c and 2d. The oil analysis must be performed at the same frequency specified for changing the oil in 40 CFR pt. 63, subp. ZZZZ, Table 2c or 2d. The analysis program must at a minimum analyze the following three parameters: Total Base Number, viscosity, and percent water content. The condemning limits for these parameters are as follows: Total Base Number is less than 30 percent of the Total Base Number of the oil when new; viscosity of the oil has changed by more than 20 percent from the viscosity of the oil when new; or percent water content (by volume) is greater than 0.5. If all of these condemning limits are not exceeded, the engine owner or operator is not required to change the oil. If any of the limits are exceeded, the engine the Permittee shall change the oil within 2 business days of receiving the results of the analysis; if the engine is not in operation when the results of the analysis are received, the Permittee shall change the oil within 2 business days or before commencing operation, whichever is later. The Permittee shall keep records of the parameters that are analyzed as part of the program, the results of the analysis, and the oil changes for the engine. The analysis program must be part of the maintenance plan for the engine.

CONTINUOUS COMPLIANCE DEMONSTRATION

40 CFR Section 63.6640(a); 40 CFR pt. 63 subp. ZZZZ, Table 6

The Permittee shall operate and maintain the stationary RICE according to the manufacturer’s emission related operation and maintenance instructions; or the Permittee shall develop and follow a maintenance plan which shall provide to the extent practicable for the maintenance and operation of the engine in a manner consistent with good air pollution control practice for minimizing emissions.


The Permittee shall operate the emergency stationary RICE according to the requirements in accordance to (f)(1) through (4) below. In order for the engine to be considered an emergency stationary RICE under 40 CFR pt. 63, subp. ZZZZ, any operation other than emergency operation, maintenance and testing, emergency



demand response, and operation in non‐emergency situations for 50 hours per year, as described in (f)(1) through (4) below, is prohibited. If the Permittee does not operate the engine according to the requirements as described (f)(1) through (4) below, the engine will not be considered an emergency engine under 40 CFR pt. 63, subp. ZZZZ and shall meet all requirements for non‐emergency engines.

40 CFR Section 63.6640(f)(1) through (4); Minn. R. 7011.8150

ON MAY 1, 2015, THE DISTRICT OF COLUMBIA CIRCUIT COURT VACATED THE PROVISIONS OF 40 CFR SECTION 63.6640(f)(2) THAT ALLOW OPERATION OF AN EMERGENCY GENERATOR WITHOUT EMISSIONS CONTROLS FOR UP TO 100 HOURS PER YEAR AS PART OF AN EMERGENCY DEMAND‐RESPONSE PROGRAM. AS OF THE DATE OF ISSUANCE OF AIR EMISSION PERMIT NO. 11500011‐003, THE COURT HAD NOT ISSUED THE MANDATE IMPLEMENTING ITS DECISION. THESE PROVISIONS REMAIN IN EFFECT UNTIL THE COURT ISSUES THE MANDATE. AFTER THAT ACTION, THE PROVISIONS WILL NO LONGER BE EFFECTIVE.

(1)There is no time limit on the use of emergency stationary RICE in emergency situations. (2) The Permittee shall operate their emergency stationary RICE for any combination of the purposes specified as described in (f)(2)(i) through (iii) below for a maximum of 100 hours per calendar year. Any operation for non‐emergency situations as allowed as described in (f)(3) and (4) counts as part of the 100 hours per calendar year allowed. (2)(i) Emergency stationary RICE may be operated for maintenance checks and readiness testing, provided that the tests are recommended by federal, state or local government, the manufacturer, the vendor, the regional transmission organization or equivalent balancing authority and transmission operator, or the insurance company associated with the engine. The Permittee may petition the Administrator for approval of additional hours to be used for maintenance checks and readiness testing, but a petition is not required if the Permittee maintains records indicating that federal, state, or local standards require maintenance and testing of emergency RICE beyond 100 hours per calendar year. (2)(ii) Emergency stationary RICE may be operated for emergency demand response for periods in which the Reliability Coordinator under the North American Electric Reliability Corporation (NERC) Reliability Standard EOP‐002‐3, Capacity and Energy



Emergencies (incorporated by reference, see 40 CFR Section 63.14), or other authorized entity as determined by the Reliability Coordinator, has declared an Energy Emergency Alert Level 2 as defined in the NERC Reliability Standard EOP‐002‐3. (3)(iii) Emergency stationary RICE may be operated for periods where there is a deviation of voltage or frequency of 5 percent or greater below standard voltage or frequency.


(4) RICE may be operated for up to 50 hours per calendar year in non‐emergency situations. The 50 hours of operation in non‐emergency situations are counted as part of the 100 hours per calendar year for maintenance and testing and emergency demand response provided as described in (f)(2) above. Except as provided in (f)(4)(i) and (ii) below, the 50 hours per year for non‐emergency situations cannot be used for peak shaving or non‐emergency demand response, or to generate income for a facility to an electric grid or otherwise supply power as part of a financial arrangement with another entity. (f)(4)(i) Prior to May 3, 2014, the 50 hours per year for non‐emergency situations can be used for peak shaving or non‐emergency demand response to generate income for a facility, or to otherwise supply power as part of a financial arrangement with another entity if the engine is operated as part of a peak shaving (load management program) with the local distribution system operator and the power is provided only to the facility itself or to support the local distribution system. (f)(4)(ii) The 50 hours per year for non‐emergency situations can be used to supply power as part of a financial arrangement with another entity if all of the following conditions are met: (A) The engine is dispatched by the local balancing authority or local transmission and distribution system operator. (B) The dispatch is intended to mitigate local transmission and/or distribution limitations so as to avert potential voltage collapse or line overloads that could lead to the interruption of power supply in a local area or region. (C) The dispatch follows reliability, emergency operation or similar protocols that follow specific NERC, regional, state, public utility commission or local standards or guidelines. (D) The power is provided only to the facility itself or to support the local transmission and distribution system.



(E) The Permittee shall identify and record the entity that dispatches the engine and the specific NERC, regional, state, public utility commission or local standards or guidelines that are being followed for dispatching the engine. The local balancing authority or local transmission and distribution system operator may keep these records on behalf of the Permittee.

40 CFR Section 63.6665 and Table 8 to Subpart ZZZZ of Part 63; 40 CFR Section 63.1 ‐ 63.15; Minn. R. 7011.8150

The Permittee shall comply with the General Provisions in 40 CFR Section 63.1 through 63.15, as applicable.

RECORDKEEPING REQUIREMENTS

Hdr RECORDKEEPING REQUIREMENTS

40 CFR Section 63.6655(e); Minn. R. 7011.8150

The Permittee shall keep records of the maintenance conducted on the stationary RICE in order to demonstrate that the Permittee operated and maintained the stationary RICE and after‐treatment control device (if any) according to the maintenance plan.

40 CFR Section 63.6660; 40 CFR Section 63.10(b)(1); Minn. R. 7011.8150; Minn. R. 7011.7000

The Permittee shall keep records in a form suitable and readily available for expeditious review according to 40 CFR Section 63.10(b)(1). As specified in 40 CFR Section 63.10(b)(1), the Permittee shall keep each record for 5 years following the date of each occurrence, measurement, maintenance, corrective action, report or record.

REPORTING REQUIREMENTS Hdr REPORTING REQUIREMENTS


The Permittee shall report each instance in which the stationary RICE did not meet each applicable emission limitation or operating limitation. These instances are deviations from the emission and operating limitations. These deviations shall be reported according to the requirements in 40 CFR Section 63.6650.


The Permittee shall report each instance in which the applicable requirements in 40 CFR pt. 63, subp. ZZZZ, Table 8 were not met.


Appendix III: Applicable Requirements for Rock Lake Telecom Emergency Generator under the area source for 40 CFR pt. 63, subp. ZZZZ


COMPLIANCE DATE 40 CFR Section 63.6595(a); Minn. R. 7011.8150

The Permittee shall comply with the applicable emission and operational limitations from 40 CFR pt. 63, subp. ZZZZ no later than October 19, 2013.

EMISSION AND OPERATIONAL REQUIREMENTS

Hdr EMISSION AND OPERATIONAL REQUIREMENTS


Change oil and filter every 500 hours of operation or annually, whichever comes first. The Permittee has the option of utilizing an oil analysis program in order to extend the oil change requirement as described below.


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


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

COMPLIANCE REQUIREMENTS

40 CFR Section 63.6605(a); Minn. R. 7011.8150

The Permittee shall be in compliance with the emission limitations and operating limitations in 40 CFR pt. 63, subp. ZZZZ that apply at all times.


At all times the Permittee shall operate and maintain any affected source, including associated air pollution control equipment and monitoring equipment, in a manner consistent with safety and good air pollution control practices for minimizing emissions. The general duty to minimize emissions does not require the Permittee to make any further efforts to reduce emissions if levels required by this standard have been achieved. Determination of whether such operation and maintenance procedures are being used will be based on information available to the Administrator which may include, but is not limited to, monitoring results, review of operation and maintenance procedures, review of operation and maintenance records, and inspection of the source.

40 CFR Section 63.6625 (e); Minn. R. 7011.8150

The Permittee shall operate and maintain the stationary RICE and after‐treatment control device (if any) according to the manufacturer’s emission‐related written instructions or develop a maintenance plan which must provide to the extent



practicable for the maintenance and operation of the engine in a manner consistent with good air pollution control practice for minimizing emissions.

40 CFR Section 63.6625(h); Minn. R. 7011.8150

The Permittee shall minimize the engine’s time spent at idle during startup and minimize the engine’s startup time to a period needed for appropriate and safe loading of the engine, not to exceed 30 minutes, after which time the emission standards applicable to all times other than startup apply.

40 CFR Section 63.6625(j); Minn. R. 7011.8150

The Permittee has the option of utilizing an oil analysis program in order to extend the specified oil change requirement. The oil analysis shall be performed at the same frequency specified for changing the oil. The analysis program shall at a minimum analyze the following three parameters: Total Acid Number, viscosity, and percent water content. The condemning limits for these parameters are as follows: Total Acid Number increases by more than 3.0 milligrams of potassium hydroxide (KOH) per gram from Total Acid Number of the oil when new; viscosity of the oil has changed by more than 20 percent from the viscosity of the oil when new; or percent water content (by volume) is greater than 0.5. (continued below)

40 CFR Section 63.6625(j); Minn. R. 7011.8150

(continued from above)If all of these condemning limits are not exceeded, the engine owner or operator is not required to change the oil. If any of the limits are exceeded, the engine owner or operator must change the oil within 2 days of receiving the results of the analysis; if the engine is not in operation when the results of the analysis are received, the engine owner or operator must change the oil within 2 days or before commencing operation, whichever is later. The owner or operator shall keep records of the parameters that are analyzed as part of the program, the results of the analysis, and the oil changes for the engine. The analysis program shall be part of the maintenance plan for the engine.

Continuous Compliance Demonstration

40 CFR Section 63.6640(a); 40 CFR pt. 63 subp. ZZZZ, Table 6

The Permittee shall operate and maintain the stationary RICE according to the manufacturer’s emission related operation and maintenance instructions; or the Permittee shall develop and follow a maintenance plan which shall provide to the extent practicable for the maintenance and operation of the engine in a manner consistent with good air pollution control practice for minimizing emissions.


The Permittee shall operate the emergency stationary RICE according to the requirements in accordance to (f)(1) through (4) below. In order for the engine to be considered an emergency stationary RICE under 40 CFR pt. 63, subp. ZZZZ, any operation other than emergency operation, maintenance and testing, emergency



demand response, and operation in non‐emergency situations for 50 hours per year, as described in (f)(1) through (4) below, is prohibited. If the Permittee does not operate the engine according to the requirements as described (f)(1) through (4) below, the engine will not be considered an emergency engine under 40 CFR pt. 63, subp. ZZZZ and shall meet all requirements for non‐emergency engines.


ON MAY 1, 2015, THE DISTRICT OF COLUMBIA CIRCUIT COURT VACATED THE PROVISIONS OF 40 CFR SECTION 63.6640(f)(2) THAT ALLOW OPERATION OF AN EMERGENCY GENERATOR WITHOUT EMISSIONS CONTROLS FOR UP TO 100 HOURS PER YEAR AS PART OF AN EMERGENCY DEMAND‐RESPONSE PROGRAM. AS OF THE DATE OF ISSUANCE OF AIR EMISSION PERMIT NO. 11500011‐003, THE COURT HAD NOT ISSUED THE MANDATE IMPLEMENTING ITS DECISION. THESE PROVISIONS REMAIN IN EFFECT UNTIL THE COURT ISSUES THE MANDATE. AFTER THAT ACTION, THE PROVISIONS WILL NO LONGER BE EFFECTIVE.

(1)There is no time limit on the use of emergency stationary RICE in emergency situations. (2) The Permittee shall operate their emergency stationary RICE for any combination of the purposes specified as described in (f)(2)(i) through (iii) below for a maximum of 100 hours per calendar year. Any operation for non‐emergency situations as allowed as described in (f)(3) and (4) counts as part of the 100 hours per calendar year allowed. (2)(i) Emergency stationary RICE may be operated for maintenance checks and readiness testing, provided that the tests are recommended by federal, state or local government, the manufacturer, the vendor, the regional transmission organization or equivalent balancing authority and transmission operator, or the insurance company associated with the engine. The Permittee may petition the Administrator for approval of additional hours to be used for maintenance checks and readiness testing, but a petition is not required if the Permittee maintains records indicating that federal, state, or local standards require maintenance and testing of emergency RICE beyond 100 hours per calendar year. (2)(ii) Emergency stationary RICE may be operated for emergency demand response for periods in which the Reliability Coordinator under the North American Electric Reliability Corporation (NERC) Reliability Standard EOP‐002‐3, Capacity and Energy


Emergencies (incorporated by reference, see 40 CFR Section 63.14), or other authorized entity as determined by the Reliability Coordinator, has declared an Energy Emergency Alert Level 2 as defined in the NERC Reliability Standard EOP‐002‐3. (3)(iii) Emergency stationary RICE may be operated for periods where there is a deviation of voltage or frequency of 5 percent or greater below standard voltage or frequency.


(4) RICE may be operated for up to 50 hours per calendar year in non‐emergency situations. The 50 hours of operation in non‐emergency situations are counted as part of the 100 hours per calendar year for maintenance and testing and emergency demand response provided as described in (f)(2) above. Except as provided in (f)(4)(i) and (ii) below, the 50 hours per year for non‐emergency situations cannot be used for peak shaving or non‐emergency demand response, or to generate income for a facility to an electric grid or otherwise supply power as part of a financial arrangement with another entity. (f)(4)(i) Prior to May 3, 2014, the 50 hours per year for non‐emergency situations can be used for peak shaving or non‐emergency demand response to generate income for a facility, or to otherwise supply power as part of a financial arrangement with another entity if the engine is operated as part of a peak shaving (load management program) with the local distribution system operator and the power is provided only to the facility itself or to support the local distribution system. (f)(4)(ii) The 50 hours per year for non‐emergency situations can be used to supply power as part of a financial arrangement with another entity if all of the following conditions are met: (A) The engine is dispatched by the local balancing authority or local transmission and distribution system operator. (B) The dispatch is intended to mitigate local transmission and/or distribution limitations so as to avert potential voltage collapse or line overloads that could lead to the interruption of power supply in a local area or region. (C) The dispatch follows reliability, emergency operation or similar protocols that follow specific NERC, regional, state, public utility commission or local standards or guidelines. (D) The power is provided only to the facility itself or to support the local transmission and distribution system. (E) The Permittee shall identify and record the entity that dispatches the engine and the specific NERC, regional, state, public utility commission or local standards or


guidelines that are being followed for dispatching the engine. The local balancing authority or local transmission and distribution system operator may keep these records on behalf of the Permittee.

40 CFR Section 63.6665 and Table 8 to Subpart ZZZZ of Part 63; 40 CFR Section 63.1 ‐ 63.15; Minn. R. 7011.8150

The Permittee shall comply with the General Provisions in 40 CFR Section 63.1 through 63.15, as applicable.

RECORDKEEPING REQUIREMENTS

Hdr RECORDKEEPING REQUIREMENTS


The Permittee shall keep records of the maintenance conducted on the stationary RICE in order to demonstrate that the Permittee operated and maintained the stationary RICE and after‐treatment control device (if any) according to the maintenance plan.

40 CFR Section 63.6660; 40 CFR Section 63.10(b)(1); Minn. R. 7011.8150

The Permittee shall keep records in a form suitable and readily available for expeditious review according to 40 CFR Section 63.10(b)(1). As specified in 40 CFR Section 63.10(b)(1), the Permittee shall keep each record for 5 years following the date of each occurrence, measurement, maintenance, corrective action, report or record.

REPORTING REQUIREMENTS Hdr REPORTING REQUIREMENTS


The Permittee shall report each instance in which the stationary RICE did not meet each applicable emission limitation or operating limitation. These instances are deviations from the emission and operating limitations. These deviations shall be reported according to the requirements in 40 CFR Section 63.6650.


The Permittee shall report each instance in which the applicable requirements in 40 CFR pt. 63, subp. ZZZZ, Table 8 were not met.

Technical Support Document, Permit Action Number: 11500011‐003 Page 1 of 9

TECHNICAL SUPPORT DOCUMENT For

AIR EMISSION PERMIT NO. 11500011‐003 This technical support document (TSD) is intended for all parties interested in the 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 determination to issue the 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 – Rock Lake 1655 Main Street Pine City, Pine County, Minnesota 55063

Contact: Greg Archer Phone: 763‐445‐5206

1.2 Facility Description Great River Energy‐ Rock Lake operates a single simple‐cycle 29.3‐megawatt GE Combustion Turbine.

In addition, there are the following insignificant activities: one black start diesel engine, Telecom

building LP emergency generator, 200,000‐gallon aboveground No. 2 fuel oil storage tank and associated

fuel oil piping, and unpaved roads.

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

Clean Air Interstate Rule (CAIR) but is now subject to the Transport Rule (TR)/Cross‐State Air Pollutant

Rule (CASPR).

1.3 Description of the Activities Allowed by this Permit Action This permit action is a 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

12/10/2012 4219 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

19.10 19.10 17.62 80.36 1400 5.25 260,327 0.65 1.26 2.05

Total Facility Actual Emissions (2013)

0.0096 0.0070 0.0086 0.0032 1.9 0.0070 * 0.00087 *

*Not reported in MN emission inventory.

Table 4. Facility Classification Classification Major 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.

Updated insignificant activities.

Appendices II and III were added to the permit. Appendix II contains the 40 CFR pt. 63, subp. ZZZZ requirements for black start diesel engine and Appendix III contains the 40 CFR pt. 63, subp. ZZZZ requirements for the emergency generator since the facility is an area source.

Fuel certification no longer necessary for compliance with Minn. R. 7011.2300; therefore, the requirement was removed from EU 001. The fuel type will meet the requirements of 40 CFR Section 80.510(c), of less than 15 parts per million (ppm).

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.

The monitoring equipment calibration is required and the fuel flow meter has being calibrated consistent with 40 CFR Section 75.19, as incorporated into the facility operational procedures. The methodology for EU 001 is consistent with the previous CAIR and now CSAPR monitoring requirements.

2. Regulatory and/or Statutory Basis New Source Review The facility is an existing 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) The construction of this turbine commenced on July 1, 1977; therefore 40 CFR pt. 60, subp. GG (effective date is October 3, 1977) does not apply. The Permittee has stated that no New Source Performance Standards apply to the operations at this facility. National Emission Standards for Hazardous Air Pollutants (NESHAP) The facility emits less than 10/25 tons per year for single and total HAPs. The facility is a true minor source for HAPs; therefore, the only applicable area source NESHAPs apply to the facility is 40 CFR pt. 63, subp. ZZZZ. On May 1st, 2015, the D.C. Circuit court vacated the RICE Rule’s 100 hour Emission Control Exemption for

Emergency Backup Generators (USCA Case #13‐1093, Document # 1550129) under 40 CFR

§63.6640(f)(2). On May 22, 2015, D.C. Circuit court granted EPA’s motion for extension of time to file a

petition for panel rehearing or rehearing en banc, or a motion to stay the mandate. Any petition for

panel rehearing or rehearing en banc, or motion to stay the mandate is now due July 15, 2015, (USCA

Case # 13‐1093, Document #1553910). Therefore the requirements are in effect until July 15, 2015. After

that date, the Permittee must comply in manner that is consistent with court order with respect to 40

CFR Section 63.6640(f)(2).

A combustion turbine (EU001) is 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. Acid Rain Program This not an affected facility under the acid rain program, 40 CFR pt. 72.6(b)(1). Construction of this turbine commenced on July 1, 1977, before the January 1, 2000, effective date of the acid rain program.


Clean Air Interstate Rule (CAIR) and the Transport Rule (TR)/Cross‐State Air Pollution Rule (CSAPR)

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

Great River Energy‐ Rock Lake 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. CSAPR is effective. CAIR is no longer applicable.

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 for CSAPR.

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

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

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

Total Facility (TF)

Minn. R. chs. 7002, 7007, 7009, 7017, 7019, 7030

Table A contains some requirements that apply to some facilities in Minnesota. Reporting and monitoring requirements are contained in Table B of this permit.

TF 40 CFR pt. 50; Minn. Stat. Section 116.07; Minn. R. 7007.0100; Minn. R. 7009‐0010‐0080

Modeling requirements to ensure that emissions do not cause violation of the National Ambient Air Quality Standards (NAAQS).


Subject Item* Applicable Regulations Rationale

TF 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.

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/Cross‐State Air Pollution Rule (CSAPR). The rule applies to NOx and SO2.

*Location of the requirement in the permit (e.g., EU, SV, GP, etc.). 3. Technical Information 3.1 Calculations of Potential to Emit Attachment 1 to this TSD contains Form GI‐07, which summarizes the PTE of the Facility, while Attachment 2 contains detailed spreadsheets and supporting information prepared by the Permittee and audited and approved by the MPCA staff. PTE emissions were calculated using the maximum heat input rating and emission factors from EPA’s AP‐42 for PM, SO2, NOx, VOC, CO and Lead. PM2.5 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. Carbon dioxide equivalent includes CO2 emissions as well as emissions of CH4 and N2O calculated using Global Warming Potential (GWP) emissions factors taken from EPA 40 CFR pt. 98, tables C‐1 and C‐2. 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

EU 001 (Combustion Turbine)

SO2: 0.50 lb/mmBtu heat input Opacity: ≤ 20 % (Minn. R. 7011.2300) Fuel Type: No. 2 fuel oil/diesel fuel (Minn. R. 7005.0100) Fuel Monitoring (CSAPR)

Recordkeeping: Monthly records of fuel type and usage CMS: Maintain and record the fuel used 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 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 using low‐sulfur fuel oil content of less than 0.050 percent by weight; therefore, no additional monitoring is required for SO2. In addition, EU 001 does have a calibrated and certified fuel flow monitor, consistent with EPA 40 CFR pt. 75, Low Mass Emissions (LME) requirements, which was installed to comply with CAIR and now CSAPR requirements under 40 CFR 75.19.

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

Table 7. Insignificant Activities

Insignificant Activity General Applicable

Emission limit Discussion

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.


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. [200,000 gals fuel oil storage

tank and associated piping]

Minn. R. 7011.1505

There are no standards of performance applicable for storage vessels/tanks.

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 emergency generator SG020]

SO2 ≤ 0.50 lb/MMBtu

Opacity ≤ 20%

(Minn. R. 7011.2300)

40 CFR pt. 63, subp. ZZZZ

This is an emergency generator. Based on EPA

published emission factors; it is highly unlikely that

they could violate the applicable requirements.

The area source requirements for 40 CFR pt. 63,

subp. ZZZZ are included in the appendix III of the

permit.

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.

[Diesel Black Start Engine]

SO2 ≤ 0.50 lb/MMBtuOpacity ≤ 20% (Minn. R. 7011.2300) 40 CFR pt. 63, subp. ZZZZ

Based on the diesel fuel used, the horsepower rating of the engine, and EPA published emission factors; it is highly unlikely that they could violate the applicable requirements. The area source requirements for 40 CFR pt. 63, subp. ZZZZ are included in the appendix II of the permit.

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. 3.6 Comments Received Public Notice Period: May 8, 2015 – June 8, 2015 EPA 45‐day Review Period: May 8, 2015 ‐ June 23, 2015 Comments were received from the Permittee during the comment period and none of the comments triggered for a re‐starting of the 45‐day review period. See attachment 4 for comments and responses. 4. Permit Fee Assessment


This permit action is the reissuance of an individual Part 70; therefore, no application fees or additional points fees apply under Minn. R. 7002.0016, subp. 1. 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. 11500011‐003 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. 147D; DQ 4219 Attachments: 1. Facility Description and CD‐01 Forms

2. PTE Summary Calculation Spreadsheets 3. Points Calculator 4. Comments from the Permittee’s comments dated June 4, 2015 and responses from

the MPCA

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 4‐ Comments from the Permittee’s comments dated June 4, 2015 and responses from the MPCA

(Available electronically in Delta under DQ No. 4219)

Attachment 1- PTE Summary Calculation Spreadsheets

EU001

Great River EnergyFacility Rock LakePermit No. 11500011-003

EU001 - Potential to Emit Calculations6-Dec-12

POLLUTANT

Emission Factor

(lb/mmBtu)Fuel Input

(mmBtu/hr)Emission Rate

(lb/hr) tpy

Criteria PollutantsVolatile organic compounds (VOC) 4.10E-04 363.3 1.49E-01 0.65Nitrogen oxides (NOx) 8.80E-01 363.3 3.20E+02 1,400.30Methane (CH4) 2.20E-03 363.3 7.99E-01 3.50Nitrous Oxide (NO2) 2.20E-04 363.3 7.99E-02 0.35

Carbon dioxide equivalent (CO2e)(1) 1.64E+02 363.3 5.94E+04 260,327.24

Sulfur dioxide 0.0505 363.3 1.83E+01 80.36Carbon monoxide 3.30E-03 363.3 1.20E+00 5.25Lead 1.40E-05 363.3 5.09E-03 0.02PM10 1.20E-02 363.3 4.36E+00 19.10PM(total) 1.20E-02 363.3 4.36E+00 19.10

PM2.5(2) 1.11E-02 363.3 4.02E+00 17.62

Hazardous Air PollutantsArsenic 1.10E-05 363.3 4.00E-03 0.02Benzene 5.50E-05 363.3 2.00E-02 0.09Beryllium 3.10E-07 363.3 1.13E-04 0.001,3-Butadiene 1.60E-05 363.3 5.81E-03 0.03Cadmium 4.80E-06 363.3 1.74E-03 0.01Chromium 1.10E-05 363.3 4.00E-03 0.02Formaldehyde 2.80E-04 363.3 1.02E-01 0.45Lead 1.40E-05 363.3 5.09E-03 0.02Manganese 7.90E-04 363.3 2.87E-01 1.26Mercury 1.20E-06 363.3 4.36E-04 0.00Naphthalene 3.50E-05 363.3 1.27E-02 0.06Nickel 4.60E-06 363.3 1.67E-03 0.01Polycyclic aromatic hydrocarbons (PAH) 4.00E-05 363.3 1.45E-02 0.06Selenium 2.50E-05 363.3 9.08E-03 0.04Total HAPs 2.05REFERENCES:1. Carbon dioxide equivalent 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

2. EPA WebFire provides PM 2.5-PRI at 1.107E-02 for "controlled" sources. For other PM emission factors in AP-42, the

"uncontrolled" values match the WebFire "controlled" values . Therefore since WebFire does not provide a PM 2.5

Page 1

EU001

"uncontrolled" emission factor, we assume that the WebFire "controlled" emission factor for PM 2.5-PRI is representative of "uncontrolled" PM 2.5.

Page 2

Gre

at R

iver

En

erg

yF

acili

tyR

ock

lake

Per

mit

#11

5000

11

Gen

erat

or

Tel

ecom

LP

Gen

erat

or

Mo

del

Gen

erac

SG

020

kW20

Rat

ed In

pu

t1.

65ga

l/hr

Pro

pane

144

cf/h

rP

ropa

ne

0.09

1m

mbt

u/ga

lP

ropa

ne -

40C

FR

98 C

-1

Em

issi

on

Fac

tor

(1)

Em

issi

on

Rat

eP

ote

nti

al

to E

mit

(2)

lb/g

al

lb/h

rtp

y

PM

0.00

50.

008

0.00

2

PM

100.

005

0.00

80.

002

PM

2.5

(5)

0.00

50.

008

0.00

2

SO

x0.

0003

50.

001

0.00

0

NO

x0.

139

0.23

00.

057

VO

C0.

083

0.13

70.

034

CO

0.12

90.

213

0.05

3

Lea

d0

00

CO

2e (

6)20

.39

5.10

(1)

Em

issi

on f

acto

rs a

re f

rom

MP

CA

Tab

le E

C-0

3.1

Rec

ipro

catin

g E

ngin

e P

ropa

ne

(2)

Pot

entia

l to

emit

is c

alcu

late

d ba

sed

on E

PA

em

erge

ncy

gene

rato

r m

emo

at 5

00 h

ours

per

yea

r

(3)

Thi

s em

issi

on s

ourc

e is

an

insi

gnifi

cant

act

ivity

und

er M

N R

ules

700

7.13

00 S

ubo

(I)

sinc

e po

tent

ial

emis

sion

s ar

e le

ss th

an 1

tpy

for

the

liste

d po

lluta

nts.

(4)

Acc

ordi

ng to

MN

Rul

es 7

007.

1250

Sub

p. 1

(B),

lb/h

r em

issi

ons

are

less

than

app

licab

le th

resh

olds

,w

hich

wou

ld tr

igge

r a

perm

it am

endm

ent.

Upd

ate

perm

it w

hen

rene

wed

.(5

) P

M2.

5 co

nser

vativ

ely

assu

med

to b

e eq

ual t

o P

M10

(6)

CO

2e v

alue

fro

m E

PA

40

CF

R P

art 9

8 T

able

s C

1 an

d C

2, c

onve

rted

to G

WP

.

kg/h

rto

nn

es/h

rto

nn

es/y

rto

nn

es C

O2e

/yr

ton

s C

O2e

/yr

lb/h

rN

ote

CH

40.

0001

5037

41.

5037

4E-0

77.

519E

-05

0.00

1879

672

0.00

2071

963

0.00

8288

Tab

le C

2 -

nat g

as

N2O

1.50

374E

-05

1.50

374E

-08

7.51

9E-0

60.

0022

4056

90.

0024

6977

90.

0098

79T

able

C2

- na

t gas

CO

29.

2419

7193

40.

0092

4197

24.

6209

864.

6209

8596

75.

0937

1283

220

.374

85T

able

C1

- P

ropa

ne5.

0982

5457

420

.393

02

Great River EnergyFacility Rock LakePermit# 11500011Unit# IA-Diesel Black Start EngineDiesel Start Eng. Massaro Detroit Diesel AlisonModel 7123-7000 V12 #2 Fuel OilRated Output 500.00 hp Rated Input (5) 3.5 mmBtu/hr

Emission Factor (1)

Emission Rate

Potential to Emit (2)

Actual' Emissions (3)

lb/hp-hr lb/hr tpy tpy

PM 2.20E-03 1.100 4.818 0.039PM10 2.20E-03 1.100 4.818 0.039PM2.5 (a) 2.20E-03 1.100 4.818 0.039SOx 2.05E-03 1.025 4.490 0.036NOx 3.10E-02 15.50 67.89 0.543CO2e (b) 1.15E+00 577 2,527 20.20VOC 2.51E-03 1.257 5.506 0.044CO 6.68E-03 3.340 14.63 0.117Lead 0.00 0.00 0.00 0.000

Emission Factor (4)

Emission Factor

Emission Rate

Potential to Emit (2)

Restricted Emissions (3)

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) Esimtate actual emissions calcualted at 70 hours per year, as a worst case assumption. 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

kg/hr tonnes/hr tonnes/year tonnes CO2e/year tons CO2e/yearCH4 0.0105 0.0000105 0.09198 2.2995 2.53473885N2O 0.0021 0.0000021 0.018396 5.482008 6.042817418

8.577556268Total tpy 2527.5776 5055155 lbs/year

577.0725 lbs/hr

1.154145 lbs/hp-hr

Attachment 2- Facility Description and CD-01 Forms

MIN

NE

SOTA

PO

LL

UT

ION

CO

NT

RO

L A

GE

NC

YA

IR Q

UA

LIT

Y52

0 L

AFA

YE

TT

E R

OA

DS

T. P

AU

L, M

N 5

5155

-419

4

Sho

w:

Act

ive

and

Pen

ding

Rec

ords

Act

ion:

PE

R 0

03

AQ

D F

acili

ty ID

:11

5000

11

Fac

ility

Nam

e:G

reat

Riv

er E

nerg

y -

Roc

k La

ke

24 J

une,

201

5 1

5:43

FAC

ILIT

Y D

ESC

RIP

TIO

N: S

TAC

K/V

EN

TS

(SV

)

ID N

o.D

isch

arge

Dire

ctio

nF

low

Rat

e/Te

mpe

ratu

reIn

form

atio

n S

ourc

e

Exi

t G

asTe

mpe

ratu

reat

Top

(ºF

)

Des

ign

Flo

w R

ate

at T

op(A

CF

M)

Wid

th(f

eet)

Dia

met

eror

Len

gth

(fee

t)

Insi

de D

imen

sion

sH

eigh

t of

Ope

ning

Fro

mG

roun

d(f

eet)

Add

edB

y(A

ctio

n)

Ret

ired

By

(Act

ion)

Ope

rato

rID

for

Item

Ope

rato

rs D

escr

iptio

nS

tack

/V

ent

Sta

tus

1S

V 0

01U

p, N

o C

apM

anuf

actu

rer

842

5626

8710

.50

12.7

535

.0P

ER

001

Act

ive

Pag

e 1

of

1

ST.

PA

UL

, MN

551

55-4

194

Sho

w:

Act

ive

and

Pen

ding

Rec

ords

Act

ion:

PE

R 0

03

AQ

D F

acili

ty ID

:11

5000

11

Fac

ility

Nam

e:MIN

NE

SOTA

PO

LL

UT

ION

CO

NT

RO

L A

GE

NC

YA

IR Q

UA

LIT

Y52

0 L

AFA

YE

TT

E R

OA

D

24 J

une,

201

5 1

5:44

FAC

ILIT

Y D

ESC

RIP

TIO

N: E

MIS

SIO

N U

NIT

(EU

)

Max

Fue

lIn

put

(mil

Btu

)

Gre

at R

iver

Ene

rgy

- R

ock

Lake

Ret

ired

By

(Act

ion)

Ope

rato

r D

escr

iptio

nID

No.

Em

issi

onU

nit

Sta

tus

Add

edB

y(A

ctio

n)

Con

trol

Equ

ip.

ID N

o(s)

.

Sta

ck/

Ven

tID

No(

s).

Ope

rato

rID

for

Item

Insi

gnif-

ican

tA

ctiv

ity

SIC

Man

ufac

ture

rM

odel

Num

ber

Max

.D

esig

nC

apac

ity

Max

imum

Des

ign

Cap

acity

Mat

eria

lsU

nits

nU

nits

d

363.

31

Com

bust

ion

Tur

bine

- 2

9.3

MW

EU

001

Act

ive

PE

R 0

02S

V 0

01E

lect

Ene

rgy

4911

GE

PG

5341

29.3

Mw

Pag

e 1

of

1 (

a)

24 J

une,

201

5 1

5:44

FAC

ILIT

Y D

ESC

RIP

TIO

N: E

MIS

SIO

N U

NIT

(EU

)

ID N

o.E

leva

tor

Type

Bot

tlene

ckP

ct.

Fue

l/S

pace

Hea

t

Firi

ng M

etho

dA

dded

By

(Act

ion)

Rem

oval

Dat

eIn

itial

Sta

rtup

Dat

e

Com

m-

ence

Con

st.

Dat

e

Em

issi

onU

nit

Sta

tus

1E

U 0

01P

ER

002

04/0

8/19

78

09/0

1/19

77

Act

ive

Pag

e 1

of

1 (

b)

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

24 June, 2015 15:46

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

Show: Active and Pending Records

AQD Facility ID:

Facility Name:

11500011

Great River Energy - Rock Lake

Item UnrestrictedPotential

(tons per yr)

LimitedPotential

(tons per yr)

ActualEmissions

(tons per yr)

Pollutant AddedBy

(Action)

RetiredBy

(Action)

HourlyPotential

(lbs per hr)

EU 001

Benzene PER 002 8.80E-022.00E-02 8.80E-02

Arsenic compounds PER 002 1.80E-024.00E-03 1.80E-02

1,3-Butadiene PER 002 2.50E-025.81E-03 2.50E-02

Beryllium PER 002 4.90E-041.13E-04 4.90E-04

Carbon Dioxide Equivalent PER 003 2.60E+055.94E+04 2.60E+05

Cadmium compounds PER 002 8.00E-031.74E-03 8.00E-03

Methane PER 003 3.50E+008.00E-01 3.50E+00

Carbon Monoxide PER 001 6.00E-021.20E+00 5.25E+00

Carbon Monoxide PER 003 5.25E+001.20E+00 5.25E+00

Carbon Dioxide PER 003 2.60E+055.94E+04 2.60E+05

Chromium compounds PER 002 1.80E-024.00E-03 1.80E-02

Formaldehyde PER 002 4.46E-011.02E-01 4.46E-01

Naphthalene PER 002 5.60E-021.27E-02 5.60E-02

HAPs - Total PER 002 2.05E+004.70E-01 2.05E+00

Mercury PER 002 2.00E-034.36E-04 2.00E-03

Manganese compounds PER 002 1.26E+002.87E-01 1.26E+00

Nitrous Oxide PER 003 3.50E-018.00E-02 3.50E-01

Nickel compounds PER 002 7.00E-031.67E-03 7.00E-03

Nitrogen Oxides PER 001 1.47E+013.20E+02 1.40E+03

Nitrogen Oxides PER 003 1.40E+033.20E+02 1.40E+03

PM < 2.5 micron PER 003 1.76E+014.02E+00 1.76E+01

Lead PER 002 2.20E-025.09E-03 2.20E-02

PM < 10 micron PER 001 2.00E-014.36E+00 1.91E+01

PM < 10 micron PER 003 1.91E+014.36E+00 1.91E+01

Polycyclic organic matter PER 002 6.40E-021.45E-02 6.40E-02

Total Particulate Matter PER 001 2.00E-014.36E+00 1.91E+01

Total Particulate Matter PER 003 1.91E+014.36E+00 1.91E+01

Selenium compounds PER 002 4.00E-029.08E-03 4.00E-02

Sulfur Dioxide PER 001 8.42E+001.82E+02 7.96E+02

Sulfur Dioxide PER 003 8.04E+011.82E+02 8.04E+01

Volatile Organic Compounds PER 001 1.00E-021.50E-01 6.50E-01

Volatile Organic Compounds PER 003 6.50E-011.50E-01 6.50E-01

Page 1 of 1

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

Facility Name: Great River Energy - Rock Lake


24 Jun, 2015 15:40Page 1 of 5

Subject Item: Total Facility

NC/CA

Type Citation Requirement

CD hdr 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 52.39

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 for CSAPR.

5.0

CD hdr DETERMINING IF A PROJECT/MODIFICATION IS SUBJECT TO NEW SOURCEREVIEW

6.0

CD Title I Condition: 40 CFR Section52.21(r)(6); Minn. R. 7007.3000;Minn. R. 7007.0800, subp. 2

These requirements apply where there is a reasonable possibility (as defined in 40CFR Section 52.21(r)(6)(vi)) that a proposed project, analyzed using theactual-to-projected-actual (ATPA) test (either by itself or as part of the hybrid testdescribed in 40 CFR Section 52.21(a)(2)(iv)(f)) and found to not be part of a majormodification, may result in a significant emissions increase. If the ATPA test is notused for a particular project, or if there is not a reasonable possibility that theproposed project could result in a significant emissions increase, then theserequirements do not apply to that project.

Even though a particular modification is not subject to New Source Review, apermit amendment, recordkeeping, or notification may still be required under Minn.R. 7007.1150 - 7007.1500.

7.0

CD Title I Condition: 40 CFR Section52.21(r)(6); Minn. R. 7007.3000;Minn. R. 7007.1200, subp. 4;Minn. R. 7007.0800, subps. 4 & 5

Preconstruction Documentation -- Before beginning actual construction on aproject, the Permittee shall document the following:

1. Project description2. Identification of any emission unit (EU) whose emissions of an NSR pollutantcould be affected3. Pre-change potential emissions of any affected existing EU, and the projectedpost-change potential emissions of any affected existing or new EU.4. A description of the applicability test used to determine that the project is not amajor modification for any regulated NSR pollutant, including the baseline actualemissions, the projected actual emissions, the amount of emissions excluded dueto increases not associated with the modification and that the EU could haveaccommodated during the baseline period, an explanation of why the amountswere excluded, and any creditable contemporaneous increases and decreases thatwere considered in the determination.

The Permittee shall maintain records of this documentation.

8.0

CD Title I Condition: 40 CFR Section52.21(r)(6); Minn. R. 7007.3000;Minn. R. 7007.0800, subps. 4 & 5

The Permittee shall monitor the actual emissions of any regulated NSR pollutantthat could increase as a result of the project and that were analyzed using theATPA test, and the potential emissions of any regulated NSR pollutant that couldincrease as a result of the project and that were analyzed using potential emissionsin the hybrid test. The Permittee shall calculate and maintain a record of the sum ofthe actual and potential (if the hybrid test was used in the analysis) emissions of theregulated pollutant, in tons per year on a calendar year basis, for a period of 5years following resumption of regular operations after the change, or for a period of10 years following resumption of regular operations after the change if the projectincreases the design capacity of or potential to emit of any unit associated with theproject.

9.0




24 Jun, 2015 15:40Page 2 of 5

CD Title I Condition: 40 CFR Section52.21(r)(6); Minn. R. 7007.3000;Minn. R. 7007.0800, subps. 4 & 5

The Permittee must submit a report to the Agency if the annual summed (actual,plus potential if used in hybrid test) emissions differ from the preconstructionprojection and exceed the baseline actual emissions by a significant amount aslisted at 40 CFR Section 52.21(b)(23). Such report shall be submitted to theAgency within 60 days after the end of the year in which the exceedances occur.The report shall contain:

a. The name and ID number of the facility, and the name and telephone number ofthe facility contact personb. The annual emissions (actual, plus potential if any part of the project wasanalyzed using the hybrid test) for each pollutant for which the preconstructionprojection and significant emissions increase are exceeded.c. Any other information, such as an explanation as to why the summed emissionsdiffer from the preconstruction projection.

10.0

CD hdr OPERATIONAL REQUIREMENTS11.0

CD 40 CFR pt. 50; Minn. Stat. Section116.07, subds. 4a & 9; Minn. R.7007.0100, subps. 7A, 7L & 7M;Minn. R. 7007.0800, subps. 1, 2 &4; Minn. R. 7009.0010-7009.0080

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.

12.0

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 theappendices.

13.0

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.

14.0

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. 11500011-003, the facility does not have any airpollution control equipment.

15.0

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. 11500011-003, the facility does not have any air pollution control equipment.

16.0

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.

17.0

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.

18.0

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

19.0

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).

20.0

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

21.0

CD hdr MONITORING REQUIREMENTS22.0




24 Jun, 2015 15:40Page 3 of 5

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; or3. Calibrate according to 40 CFR pt. 75.

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.

23.0

CD Minn. R. 7007.0800, subp. 4(D) Operation of Monitoring Equipment: Unless otherwise noted in Tables A and/or 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.

24.0

CD hdr RECORDKEEPING25.0

CD Minn. R. 7007.0800, subp. 5(C) Recordkeeping: Retain all records at the Great River Energy headquarters, 12300Elm Creek Boulevard, Maple Grove, Minnesota, 55369 for a period of five (5) yearsfrom the date of monitoring, sample, measurement, or report. Records which mustbe retained at this location include all calibration and maintenance records, alloriginal recordings for continuous monitoring instrumentation, and copies of allreports required by the permit. Records must conform to the requirements listed inMinn. R. 7007.0800, subp. 5(A).

26.0

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.

27.0

CD Minn. R. 7007.1200, subp. 4 When the Permittee determines that no permit amendment or notification isrequired prior to making a change, the Permittee must retain records of allcalculations required under Minn. R. 7007.1200. These records shall be kept for aperiod of five years from the date the change was made or until permit reissuance,whichever is longer. The records shall be kept at the stationary source for thecurrent calendar year of operation and may be kept at the stationary source oroffice of the stationary source for all other years. The records may be maintained ineither electronic or paper format.

28.0

CD hdr REPORTING/SUBMITTALS29.0

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, B,and 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.

30.0

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.

31.0

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.

32.0




24 Jun, 2015 15:40Page 4 of 5

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.

33.0

S/A Minn. R. 7007.0800, subp. 6(A)(2) Semiannual Deviations Report: due 30 days after end of each calendar half-yearstarting 06/09/2008 following permit issuance. The first semiannual reportsubmitted by the Permittee shall cover the calendar half-year in which the permit isissued. The first report of each calendar year covers January 1 - June 30. Thesecond report of each calendar year covers July 1 - December 31. If no deviationshave occurred, the Permittee shall submit the report stating no deviations.

34.0

CD Minn. R. 7007.1150 - Minn. R.7007.1500

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

35.0

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

36.0

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).

37.0

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

38.0

CD Minn. R. 7019.3000 - Minn. R.7019.3010

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.

39.0

CD Minn. R. 7002.0005 - Minn. R.7002.0095

Emission Fees: due 30 days after receipt of an MPCA bill.40.0




24 Jun, 2015 15:40Page 5 of 5

Subject Item: EU 001 Combustion Turbine - 29.3 MW

Associated Items: SV 001

NC/CA

Type Citation Requirement

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

1.0

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 . The potential to emit from the unit is 0.051 lb/MMBtu due toequipment design and allowable fuels.

2.0

CD Minn. R. 7005.0100, subp. 35a Fuel type: No. 2 fuel oil/diesel fuel meeting the requirements of 40 CFR Section80.510(c) only by design.

3.0

CD Minn. R. 7007.0800, subp. 5 Fuel Monthly Recordkeeping: The Permittee shall keep records of fuel type andusage on a monthly basis.

4.0

CD 40 CFR pt. 97; 40 CFR 75.19;Minn. R. 7007.0800, subps. 4 and5

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

5.0

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

6.0

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 reliability.

7.0

Attachment 3- Points Calculator

Points Calculator

1) AQ Facility ID No.: 147D Total Points 02) Facility Name: Great River Energy-Rock Lake3) Small business? y/n? N 4) DQ Numbers (including all rolled) : 4219 5) Date of each Application Received: 12/10/20126) Final Permit No. 11500011-0037) 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 0

NOTES: This permit is a reissuance; therefore no additional points are required for this reissuance.

(DQ DQ 4219)

Permit Notice to the Permittee Permit Shield Facility ... · Total Facility Operating Permit...

Documents

Transcript of Permit Notice to the Permittee Permit Shield Facility ... · Total Facility Operating Permit...