Air Individual Permit Major Amendment Permit characteristics: State; Limits to avoid Part 70/ True minor for NSR; True Minor for NSR

Transcription

1 Air Individual Permit Major Amendment Permittee: Facility name: Northern Natural Gas Co - Faribault Northern Natural Gas Co - Faribault Canby Ave Faribault, MN Rice County Operating permit issuance date: June 5, 1996 Expiration date: Permit does not expire All Title I Conditions do not expire Major Amendment: March 28, 2017 Permit characteristics: State; Limits to avoid Part 70/ True minor for NSR; True Minor for NSR The emission units, control equipment and emission stacks at the stationary source authorized in this permit amendment are as described in the Permit Applications Table. This permit amendment supersedes Air Emission Permit No and authorizes the Permittee to operate, construct, and modify the stationary source at the address listed above unless otherwise noted in the permit. The Permittee must comply with all the conditions of the permit. Any changes or modifications to the stationary source must be performed in compliance with Minn. R to Terms used in the permit are as defined in the state air pollution control rules unless the term is explicitly defined in the permit. Unless otherwise indicated, all the Minnesota rules cited as the origin of the permit terms are incorporated into the SIP under 40 CFR and as such as are enforceable by EPA Administrator or citizens under the Clean Air Act. Signature: for Steve S. Pak This document has been electronically signed. Don Smith, P.E., Manager Air Quality Permits Section Industrial Division for the Minnesota Pollution Control Agency

2 Table of Contents 1. Permit applications table Where to send submittals Facility description... 5 Amendment description Summary of subject items Limits and other requirements Submittal/action requirements Appendices Appendix A. Equations for COMG Appendix B. Emission Calculations for EQUI Appendix C. Emission Calculations for EQUI Page

3 Permit issued: March 28, Permit expires: Non Expiring Page 3 of Permit applications table Subsequent permit applications: Title description Application receipt date Action number State Permit 01/29/ Major Amendment 01/24/ Administrative Amendment Not Applicable* Major Amendment 05/20/ Major Amendment (Supplemental Information) 07/29/ *Application date is not applicable because the Administrative Amendment was a MPCA initiated reopening to edit and update requirements in the Delta database.

4 Permit issued: March 28, Permit expires: Non Expiring Page 4 of Where to send submittals 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 Each submittal must be postmarked or received by the date specified in the applicable Table. Those submittals required by Minn. R to must be certified by a responsible official, defined in Minn. R , subp. 21. Other submittals shall be certified as appropriate if certification is required by an applicable rule or permit condition. 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 Send any application for a permit or permit amendment to: Fiscal Services 6 th Floor Minnesota Pollution Control Agency 520 Lafayette Road North St. Paul, Minnesota Also, where required by an applicable rule or permit condition, send to the Permit Document Coordinator notices of: a. Accumulated insignificant activities b. Installation of control equipment c. Replacement of an emissions unit, and d. Changes that contravene a permit term 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

5 Permit issued: March 28, Permit expires: Non Expiring Page 5 of Facility description Northern Natural Gas Co - Faribault Compressor (NNG or Facility) is a natural gas compressor station located at Canby Ave in Faribault, MN, Rice County, Minnesota. Compressor stations compress natural gas to a specified pressure along natural gas pipelines allowing the gas to continue moving through the pipeline to an intended recipient. The main contributing sources of air pollution include nitrogen oxides (NO X), carbon monoxide (CO), and sulfur dioxide (SO 2). Amendment description This permit action is for construction of a turbine (EQUI 4), an emergency generator (EQUI 5) to replace diesel emergency engine (EQUI 1), and two process heaters (EQUI 6 and 7). With the addition of the new emission units, the facility potential to emit (PTE) for NO X, CO, and SO 2 exceeds Part 70 permit thresholds. Limits on emissions of NO X, CO, and fuel sulfur content to limit SO 2 have been incorporated into the permit so that NNG is a Part 70 synthetic minor source.

6 Permit issued: March 28, Permit expires: Non Expiring Page 6 of Summary of subject items SI ID: Relationshi Description p Type COMG2: Limits to has avoid Part 70 members EQUI1: Emergency Generator EQUI2: Natural Gas sends to Turbine EQUI4: Solar mars Turbine S EQUI5: Reciprocating IC Engine sends to sends to Related SI ID: Description EQUI2, EQUI4 STRU1: Solar Mars Turbine T15000S Stack STRU3: Solar Mars Turbine S Stack STRU4: Caterpillar G3512 Generator Stack EQUI6: Heater 1 sends to STRU5: Process Heater EQUI7: Heater 2 sends to STRU6: Process Heater FUGI1: 115 Flanges FUGI2: 1 SI ID: Description Compressor Seal FUGI3: 60 Valves STRU1: Solar Mars Turbine T15000S Stack STRU2: STRU3: Solar Mars Turbine S Stack STRU4: Caterpillar G3512 Generator Stack STRU5: Process Heater STRU6: Process Heater TFAC1: Northern Natural Gas Co - Faribault Relationshi p Type receives from Related SI ID: Description EQUI1: Emergency Generator

7 Permit Issued: March 28, Permit Expires: Non-expiring Page 7 of Limits and other requirements Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation TFAC Northern Natural Gas Co - Faribault Permit Appendices: This permit contains appendices as listed in the permit Table of Contents. The Permittee shall comply with all requirements contained in Appendix A. Emission Calculations for COMG 2, Appendix B. Emission Calculations for EQUI 4, and Appendix C. Emission Calculations for EQUI 5. [Minn. R , subp. 2] PERMIT SHIELD: Subject to the limitations in Minn. R , 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 and , subp. 2, notwithstanding the conditions of this permit specifying compliance practices for applicable requirements, any person (including the Permittee) may also use other credible evidence to establish compliance or noncompliance with applicable requirements. This permit shall not alter or affect the liability of the Permittee for any violation of applicable requirements prior to or at the time of permit issuance. [Minn. R , (A)(2)] Circumvention: Do not install or use a device or means that conceals or dilutes emissions, which would otherwise violate a federal or state air pollution control rule, without reducing the total amount of pollutant emitted. [Minn. R ] Air Pollution Control Equipment: Operate all pollution control equipment whenever the corresponding process equipment and emission units are operated. [Minn. R , subp. 16(J), Minn. R , subp. 2] Operation and Maintenance Plan: Retain at the stationary source an operation and maintenance plan for all air pollution control equipment. At a minimum, the O & M plan shall identify all air pollution control equipment and control practices and shall include a preventative maintenance program for the equipment and practices, a description of (the minimum but not necessarily the only) corrective actions to be taken to restore the equipment and practices to proper operation to meet applicable permit conditions, a description of the employee training program for proper operation and maintenance of the control equipment and practices, and the records kept to demonstrate plan implementation. [Minn. R , subp. 14, Minn. R , subp. 16(J)] Operation Changes: In any shutdown, breakdown, or deviation the Permittee shall immediately take all practical steps to modify operations to reduce the emission of any regulated air pollutant. The Commissioner may require feasible and practical modifications in the operation to reduce emissions of

8 Permit Issued: March 28, Permit Expires: Non-expiring Page 8 of 39 Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation air pollutants. No emissions units that have an unreasonable shutdown or breakdown frequency of process or control equipment shall be permitted to operate. [Minn. R , subp. 4] Fugitive Emissions: Do not cause or permit the handling, use, transporting, or storage of any material in a manner which may allow avoidable amounts of particulate matter to become airborne. Comply with all other requirements listed in Minn. R [Minn. R ] Noise: The Permittee shall comply with the noise standards set forth in Minn. R to at all times during the operation of any emission units. This is a state only requirement and is not enforceable by the EPA Administrator or citizens under the Clean Air Act. [Minn. R ] Inspections: The Permittee shall comply with the inspection procedures and requirements as found in Minn. R , subp. 9(A). [Minn. R , subp. 9(A)] The Permittee shall comply with the General Conditions listed in Minn. R , subp. 16. [Minn. R , subp. 16] Performance Testing: Conduct all performance tests in accordance with Minn. R. ch unless otherwise noted in this permit. [Minn. R. ch. 7017] Performance Test Notifications and Submittals: Performance Test Notification and Plan: due 30 days before each Performance Test Performance Test Pre-test Meeting: due 7 days before each Performance Test Performance Test Report: due 45 days after each Performance Test The Notification, Test Plan, and Test Report must be submitted in a format specified by the commissioner. [Minn. R , Minn. R , subps. 1-4, Minn. R , subps. 1-2] Limits set as a result of a performance test (conducted before or after permit issuance) apply until superseded as stated in the MPCA's Notice of Compliance letter granting preliminary approval. Preliminary approval is based on formal review of a subsequent performance test on the same unit as specified by Minn. R , subp. 3. The limit is final upon issuance of a permit amendment incorporating the change. [Minn. R , subp. 3] Monitoring Equipment Calibration - The Permittee shall either: 1. Calibrate or replace required monitoring equipment every 12 months; or 2. Calibrate at the frequency stated in the manufacturer's specifications. For each monitor, the Permittee shall maintain a record of all

9 Permit Issued: March 28, Permit Expires: Non-expiring Page 9 of 39 Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation calibrations, including the date conducted, and any corrective action that resulted. The Permittee shall include the calibration frequencies, procedures, and manufacturer's specifications (if applicable) in the Operations and Maintenance Plan. Any requirements applying to continuous emission monitors are listed separately in this permit. [Minn. R , subp. 4(D)] Operation of Monitoring Equipment: Unless noted elsewhere in this permit, monitoring a process or control equipment connected to that process is not necessary during periods when the process is shutdown, or during checks of the monitoring systems, such as calibration checks and zero and span adjustments. If monitoring records are required, they should reflect any such periods of process shutdown or checks of the monitoring system. [Minn. R , subp. 4(D)] Recordkeeping: Retain all records at the stationary source, unless otherwise specified within this permit, for a period of five (5) years from the date of monitoring, sample, measurement, or report. Records which must be retained at this location include all calibration and maintenance records, all original recordings for continuous monitoring instrumentation, and copies of all reports required by the permit. Records must conform to the requirements listed in Minn. R , subp. 5(A). [Minn. R , subp. 5(C)] Recordkeeping: Maintain records describing any insignificant modifications (as required by Minn. R , subp. 3) or changes contravening permit terms (as required by Minn. R , subp. 2), including records of the emissions resulting from those changes. [Minn. R , subp. 5(B)] If the Permittee determines that no permit amendment or notification is required prior to making a change, the Permittee must retain records of all calculations required under Minn. R These records shall be kept for a period of five years from the date that the change was made. The records shall be kept at the stationary source for the current calendar year of operation and may be kept at the stationary source or office of the stationary source for all other years. The records may be maintained in either electronic or paper format. [Minn. R , subp. 4] Shutdown Notifications: Notify the Commissioner at least 24 hours in advance of a planned shutdown of any control equipment or process equipment if the shutdown would cause any increase in the emissions of any regulated air pollutant. If the owner or operator does not have advance knowledge of the shutdown, notification shall be made to the Commissioner as soon as possible after the shutdown. However, notification is not required in the circumstances outlined in Items A, B and C of Minn. R , subp. 3. At the time of notification, the owner or operator shall inform the Commissioner of the cause of the shutdown and the

10 Permit Issued: March 28, Permit Expires: Non-expiring Page 10 of 39 Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation estimated duration. The owner or operator shall notify the Commissioner when the shutdown is over. [Minn. R , subp. 3] Breakdown Notifications: Notify the Commissioner within 24 hours of a breakdown of more than one hour duration of any control equipment or process equipment if the breakdown causes any increase in the emissions of any regulated air pollutant. The 24-hour time period starts when the breakdown was discovered or reasonably should have been discovered by the owner or operator. However, notification is not required in the circumstances outlined in Items A, B and C of Minn. R , subp. 2. At the time of notification or as soon as possible thereafter, the owner or operator shall inform the Commissioner of the cause of the breakdown and the estimated duration. The owner or operator shall notify the Commissioner when the breakdown is over. [Minn. R , subp. 2] Notification of Deviations Endangering Human Health or the Environment: As soon as possible after discovery, notify the Commissioner or the state duty officer, either orally or by facsimile, of any deviation from permit conditions which could endanger human health or the environment. [Minn. R , subp. 1] Notification of Deviations Endangering Human Health or the Environment Report: Within 2 working days of discovery, notify the Commissioner in writing of any deviation from permit conditions which could endanger human health or the environment. Include the following information in this written 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 yet corrected; and 5. steps taken or planned to reduce, eliminate, and prevent reoccurrence of the deviation. [Minn. R , subp. 1] Application for Permit Amendment: If a permit amendment is needed, submit an application in accordance with the requirements of Minn. R through Minn. R Submittal dates vary, depending on the type of amendment needed. Upon adoption of a new or amended federal applicable requirement, and if there are more than 3 years remaining in the permit term, the Permittee shall file an application for an amendment within nine months of promulgation of the applicable requirement, pursuant to Minn. R , subp. 3. [Minn. R , subp. 3, Minn. R ] Extension Requests: The Permittee may apply for an

11 Permit Issued: March 28, Permit Expires: Non-expiring Page 11 of 39 Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation Administrative Amendment to extend a deadline in a permit by no more than 120 days, provided the proposed deadline extension meets the requirements of Minn. R , subp. 1(H). Performance testing deadlines from the General Provisions of 40 CFR pt. 60 and pt. 63 are examples of deadlines for which the MPCA does not have authority to grant extensions and therefore do not meet the requirements of Minn. R , subp. 1(H). [Minn. R , subp. 1(H)] Emission Inventory Report: due on or before April 1 of each calendar year following permit issuance, to be submitted on a form approved by the Commissioner. [Minn. R ] Emission Fees: due 30 days after receipt of an MPCA bill. [Minn. R ] COMG 2 Limits to avoid Part The Permittee shall limit emissions of Nitrogen Oxides <= 90 tons per year 12-month rolling sum to be calculated by the 15th day of each month for the previous 12-month period as described in this permit. [To avoid major source under 40 CFR 70.2 & Minn. R ] The Permittee shall limit emissions of Carbon Monoxide <= 90 tons per year to be calculated by the 15th day of each month for the previous 12-month period as described in this permit. [To avoid major source under 40 CFR 70.2 & Minn. R ] Hourly Recordkeeping. When ambient temperatures are less than or equal to 2 degrees Fahrenheit and greater than or equal to 0 degrees Fahrenheit, the Permittee shall monitor the temperature every hour for temperature changes. The Permittee shall record and maintain the ambient temperature while in operation. [Minn. R , subp. 4-5] Daily Recordkeeping. Once each operating day, the Permittee shall calculate, record, and maintain the hours of operation and record and maintain the ambient temperature while in operation. This shall be based on written or electronic usage logs. [Minn. R , subps. 4-5] Monthly Recordkeeping. By the 15th day of each month, the Permittee shall calculate and record the following: 1) The total hours of operation for EQUI 2 and EQUI 4 for the previous calendar month using the daily records when ambient temperatures are equal to or greater than 0 degrees Fahrenheit; 2) The total hours of operation for EQUI 2 and EQUI 4 for the previous calendar month using the daily records when ambient temperatures are less than 0 degrees Fahrenheit; 3) The NOX emissions for the previous month using the emission factors, capacities, and equations specified in Appendix A of this permit;

12 Permit Issued: March 28, Permit Expires: Non-expiring Page 12 of 39 Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation 4) The CO emissions for the previous month using the emission factors, capacities, and equations specified in Appendix A of this permit; 5) The 12-month rolling sum NOX emissions for the previous 12-month period by summing the monthly NOX emissions data for the previous 12 months. 6) The 12-month rolling sum CO emissions for the previous 12- month period by summing the monthly CO emissions data for the previous 12 months. [Minn. R , subps. 4-5] EQUI 1 EU002 Emergency Generator Opacity <= 20 percent opacity once operating temperatures have been attained. [Minn. R , subp. 1] The Permittee shall limit emissions of Sulfur Dioxide <= 0.50 pounds per million Btu heat input. [Minn. R , subp. 2(A)] The Permittee shall limit emissions of Sulfur Dioxide <= pounds per million Btu heat input. This limit is effective on January 31, [Minn. R , subp. 2(B)] Fuel type: No. 2 fuel oil/diesel fuel only. [Minn. R , subp. 35a] Hours of Operation: The Permittee shall maintain documentation on site that the unit is an emergency generator by design that qualifies under the U.S. EPA memorandum entitled "Calculating Potential to Emit (PTE) for Emergency Generators" dated September 6, 1995, limiting operation to 500 hours per year. [Minn. R , subps. 4-5] The Permittee shall keep records of fuel type and usage on a monthly basis. [Minn. R , subp. 5] The Permittee shall; a. Change oil and filter every 500 hours of operation or annually, whichever comes first; b. Inspect air cleaner every 1,000 hours of operation or annually, whichever comes first, and replace as necessary; and c. Inspect all hoses and belts every 500 hours of operation or annually, whichever comes first, and replace as necessary. If EQUI 1 is operating during an emergency and it is not possible to shut down the engine in order to perform the management practice requirements on the schedule required above, or if performing the management practice on the required schedule would otherwise pose an unacceptable risk under federal, state, or local law, the management practice can be delayed until the emergency is over or the unacceptable risk under federal, state, or local law has abated. The management practice should be performed as soon as practicable after the emergency has ended or the unacceptable risk under federal, state, or local law has abated. Sources must report any failure to perform the management practice on the schedule required and the federal, state or

13 Permit Issued: March 28, Permit Expires: Non-expiring Page 13 of 39 Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation local law under which the risk was deemed unacceptable. [40 CFR (a), 40 CFR pt. 63, subp. ZZZZ, Table 2d, Minn. R ] If EQUI 1 operates or is contractually obligated to be available for more than 15 hours per calendar year for the purpose specified in 40 CFR (f)(4)(ii), the Permittee must use diesel fuel that meets the requirements in 40 CFR (b) for nonroad diesel fuel, except that any existing diesel fuel purchased (or otherwise obtained) prior to January 1, 2015, may be used until depleted. [40 CFR (b), Minn. R ] The Permittee must operate and maintain EQUI 1 according to the manufacturer's emission-related written instructions. [40 CFR (e), Minn. R ] The Permittee must install a non-resettable hour meter if one is not already installed. [40 CFR (f), Minn. R ] The Permittee must 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 in 40 CFR pt. 63, subp. ZZZZ, Table 2d apply. [40 CFR (h), Minn. R ] 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, Table 2d. The oil analysis must be performed at the same frequency specified for changing the oil in 40 CFR pt. 63, subp. ZZZZ, Table 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 Permittee is not required to change the oil. If any of the limits are exceeded, the Permittee must 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 must change the oil within 2 business days or before commencing operation, whichever is later. The Permittee must 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. [40 CFR (i), Minn. R ] (a) The Permittee must be in compliance with the emission limitations, operating limitations, and other requirements in 40 CFR pt. 63, subp. ZZZZ that apply at all times.

14 Permit Issued: March 28, Permit Expires: Non-expiring Page 14 of 39 Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation (b) At all times the Permittee must 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 , Minn. R ] The Permittee must demonstrate continuous compliance with each emission limitation, operating limitation, and other requirements in 40 CFR pt. 63, subp. ZZZZ, Table 2d that apply by operating and maintaining EQUI 1 according to the manufacturer's emission-related operation and maintenance instructions. [40 CFR (a), 40 CFR pt. 63, subp. ZZZZ, Table 6, Minn. R ] The Permittee must report each instance in which the requirements in 40 CFR pt. 63, subp. ZZZZ, Table 8 that apply to EQUI 1 were not met. [40 CFR (e), Minn. R ] The Permittee must operate the emergency stationary RICE according to the requirements 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 below, is prohibited. If the Permittee does not operate the engine according to the requirements below, the engine will not be considered an emergency engine under 40 CFR pt. 63, subp. ZZZZ and must meet all requirements for non-emergency engines. (1) There is no time limit on the use of emergency stationary RICE in emergency situations. (2) The Permittee may operate EQUI 1 for a maximum of 100 hours per calendar year 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

15 Permit Issued: March 28, Permit Expires: Non-expiring Page 15 of 39 Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation per calendar year. Any operation for non-emergency situations as allowed by 40 CFR (f)(4) counts as part of the 100 hours per calendar year allowed by this paragraph (f)(2). (4) EQUI 1 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 in 40 CFR (f)(2). Except as provided in 40 CFR (f)(4)(ii), 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. (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 identifies and records 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 (f), Minn. R ] (a) The Permittee must keep records as described below; (1) A copy of each notification and report that the Permittee submitted to comply with 40 CFR pt. 63, subp. ZZZZ, including all documentation supporting any Initial Notification or Notification of Compliance Status that the Permittee submitted, according to the requirement in 40 CFR 63.10(b)(2)(xiv).

16 Permit Issued: March 28, Permit Expires: Non-expiring Page 16 of 39 Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation (2) Records of the occurrence and duration of each malfunction of operation (i.e., process equipment) or the air pollution control and monitoring equipment. (3) Records of performance tests and performance evaluations as required in 40 CFR 63.10(b)(2)(viii). (4) Records of all required maintenance performed on the air pollution control and monitoring equipment. (5) Records of actions taken during periods of malfunction to minimize emissions in accordance with 40 CFR (b), including corrective actions to restore malfunctioning process and air pollution control and monitoring equipment to its normal or usual manner of operation. (d) The Permittee must keep the records required in 40 CFR pt. 63, subp. ZZZZ, Table 6 to show continuous compliance with each emission or operating limitation that applies. (f) The Permittee must keep records of the hours of operation of the engine that is recorded through the non-resettable hour meter. The Permittee must document how many hours are spent for emergency operation, including what classified the operation as emergency and how many hours are spent for non-emergency operation. If the engine is used for the purposes specified in 40 CFR (f)(4)(ii), the Permittee must keep records of the notification of the emergency situation, and the date, start time, and end time of engine operation for these purposes. [40 CFR , Minn. R ] If the Permittee operates or is contractually obligated to be available for more than 15 hours per calendar year for the purpose specified in 40 CFR (f)(4)(ii), the Permittee must submit an annual report according to the requirements below. (1) The report must contain the following information: (i) Company name and address where the engine is located. (ii) Date of the report and beginning and ending dates of the reporting period. (iii) Engine site rating and model year. (iv) Latitude and longitude of the engine in decimal degrees reported to the fifth decimal place. (vii) Hours spent for operation for the purpose specified in 40 CFR (f)(4)(ii), including the date, start time, and end time for engine operation for the purposes specified in 49 CFR

17 Permit Issued: March 28, Permit Expires: Non-expiring Page 17 of 39 Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation (f)(4)(ii). The report must also identify the entity that dispatched the engine and the situation that necessitated the dispatch of the engine. (viii) If there were no deviations from the fuel requirements in 40 CFR that apply to the engine (if any), a statement that there were no deviations from the fuel requirements during the reporting period. (ix) If there were deviations from the fuel requirements in 40 CFR that apply to the engine (if any), information on the number, duration, and cause of deviations, and the corrective action taken. (2) The first annual report must cover the calendar year 2015 and must be submitted no later than March 31, Subsequent annual reports for each calendar year must be submitted no later than March 31 of the following calendar year. (3) The annual report must be submitted electronically using the subpart specific reporting form in the Compliance and Emissions Data Reporting Interface (CEDRI) that is accessed through EPA's Central Data Exchange (CDX) ( However, if the reporting form specific to t40 CFR pt. 63, subp. ZZZZ is not available in CEDRI at the time that the report is due, the written report must be submitted to the Administrator at the appropriate address listed in 40 CFR [40 CFR (h), Minn. R ] Recordkeeping: The Permittee shall maintain files of all information required by 40 CFR pt. 63 in a form suitable and readily available for expeditious inspection and review. The files should be retained for at least 5 years following the date of each occurrence, measurement, maintenance, corrective action, report, or record. Only the most recent two years of information must be kept on site. [40 CFR 63.10(b)(1), Minn. R , subp. 2(B)] The Permittee shall maintain, at a minimum, the following information in the files: 1) the occurrence and duration of each startup, shutdown, or malfunction of operation when the startup or shutdown causes the source to exceed any applicable emission limitation in the relevant emission standards; 2) the occurrence and duration of each malfunction of operation (i.e., process equipment) or the required air pollution control and monitoring equipment; 3) all maintenance performed on the air pollution control and monitoring equipment; 4) actions taken during periods of startup, shutdown, and malfunction when such actions are different from the

18 Permit Issued: March 28, Permit Expires: Non-expiring Page 18 of 39 Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation procedures specified in the affected source's startup, shutdown, and malfunction plan (SSMP). In this case, the Permittee shall report this action within 2 days of occurrence and follow by a written notification within 7 days of occurrence; 5) all information necessary to demonstrate conformance with the affected source's SSMP and actions taken in accordance with SSMP; 6) each period during which a continuous monitoring system (CMS) is malfunctioning or inoperative; 7) all required measurements needed to demonstrate compliance with a relevant standard; 8) all results of performance test, CMS performance evaluations, and opacity and visible emission observations; 9) all measurements as may be necessary to determine the conditions of performance tests and performance evaluations; 10) all CMS calibration checks; 11) all adjustments and maintenance performed on CMS; 12) any information demonstrating whether a source is meeting the requirements for a waiver of record keeping or reporting requirements under 40 CFR pt. 63; 13) All emission levels relative to the criterion for obtaining permission to use an alternative to the relative accuracy test, if the source has been granted such permission under 40 CFR 63.8(f)(6); and 14) all documentation supporting initial notifications and notifications of compliance status. [40 CFR 63.10(b)(2), Minn. R , subp. 2(B)] Prior to construction or reconstruction of a major-emitting "affected source" under the promulgated MACT standards, the Permittee must apply for and obtain an air emission permit. [40 CFR 63.5(b)(3)& Minn. R ] After the effective date of any relevant standard promulgated by the Administrator under 40 CFR pt. 63, the Permittee who constructs a new affected source that is not major-emitting or reconstructs an affected source that is not major-emitting that is subject to such standard, or reconstructs a source such that the source becomes an affected source subject to the standard, must notify the Administrator of the intended construction or reconstruction. The notification must be submitted in accordance with the procedures in 40 CFR Section 63.9(b). [40 CFR 63.5(b)(4)& Minn. R ] After the effective date of any relevant standard promulgated by the Administrator under 40 CFR pt. 63, equipment added (or a process change) to an affected source that is within the scope of the definition of affected source under the relevant standard must be considered part of the affected source and subject to all provisions of the relevant standard established for that affected source. [40 CFR 63.5(b), Minn. R ] Circumvention. The Permittee shall not build, erect, install, or use any article, machine, equipment, or process to conceal an emission that would otherwise constitute noncompliance with

19 Permit Issued: March 28, Permit Expires: Non-expiring Page 19 of 39 Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation a relevant standard. Such concealment includes, but is not limited to: (1) The use of diluents to achieve compliance with a relevant standard based on the concentration of a pollutant in the effluent discharged to the atmosphere; or (2) The use of gaseous diluents to achieve compliance with a relevant standard for visible emissions. [40 CFR 63.4(b), Minn. R ] EQUI 2 EU001 Natural Gas Turbine Nitrogen Oxides <= percent by volume at 15 percent oxygen and on a dry basis. [40 CFR (d), Minn. R ] Sulfur Dioxide <= percent by volume at 15 percent oxygen and on a dry basis. [40 CFR (a), Minn. R ] Sulfur Dioxide <= 0.50 pounds per million Btu heat input (The potential to emit from the unit is lb/mmbtu due to equipment design and allowable fuels.). [Minn. R , subp. 2(A)] Sulfur Dioxide <= pounds per million Btu heat input This limit is effective on January 1, [Minn. R , subp. 2(B)] Opacity <= 20 percent opacity once operating temperatures have been attained. [Minn. R , subp. 1] Sulfur Content of Fuel <= 0.09 percent by weight. This limit is more stringent than 40 CFR (b). The Permittee shall comply with this limit by complying with the sulfur monitoring requirements under 40 CFR pt. 60, subp. GG. [Minn. R , subp. 2, To avoid major source under 40 CFR 70.2 & Minn. R ] Sulfur Content of Fuel <= 0.8 percent by weight. [40 CFR (b), Minn. R ] Fuel type: Natural gas only. [Minn. R , subp. 35a] Reporting: If there is a change in fuel supply, the Permittee must notify the MPCA of such change for re-examination of the custom fuel-monitoring schedule. A substantial change in fuel quality shall be considered as a change in fuel supply. Sulfur monitoring shall be conducted weekly during the interim period when this custom schedule is being reexamined. [40 CFR (b), Minn. R ] The Permittee shall keep records of fuel type and usage on a monthly basis. [Minn. R , subp. 5] Analysis for fuel sulfur content of the natural gas shall be conducted using one of the approved ASTM reference methods for the measurement of sulfur in gaseous fuels, or an approved alternative method. [40 CFR (b), Minn. R ] Sulfur monitoring shall be conducted twice monthly for six

20 Permit Issued: March 28, Permit Expires: Non-expiring Page 20 of 39 Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation months. If this monitoring shows little variability in the fuel sulfur content, and indicates consistent compliance with 40 CFR Section , then sulfur monitoring shall be conducted once per quarter for six quarters. [40 CFR (b), Minn. R ] Sulfur Monitoring: If, after the first 2 years of sulfur monitoring, the sulfur content of the fuel shows little variability and, when calculated as sulfur dioxide, represents consistent compliance with the sulfur dioxide emission limits specified under 40 CFR Section , sample analysis shall be conducted twice per annum. This monitoring shall be conducted during the first and third quarters of each calendar year. [40 CFR (b), Minn. R ] Notification of noncompliance: Should any sulfur analysis indicate noncompliance with 40 CFR Section , the Permittee shall notify the MPCA of such excess emissions and the custom fuel monitoring schedule shall be re-examined by the Administrator. Sulfur monitoring shall be conducted weekly during the interim period when this custom fuelmonitoring schedule is being re-examined. [40 CFR (b), Minn. R ] Recordkeeping: Records of sample analyses and fuel supply pertinent to the custom fuel-monitoring schedule shall be retained for a period of five years, and be available for inspection by personnel of federal, state, and local air pollution control agencies. [40 CFR (b), Minn. R ] The Permittee shall submit a notification of any physical or operational change which increases emission rate: due 60 days (or as soon as practical) before the change is commenced. [40 CFR 60.7(a)(4), Minn. R , subp. 1] Recordkeeping: The Permittee shall maintain records of the occurrence and duration of any startup, shutdown, or malfunction in the operation of the facility including; any malfunction of the air pollution control equipment; or any periods during which a continuous monitoring system or monitoring device is inoperative. [40 CFR 60.7(b), Minn. R , subp. 1] Recordkeeping: The Permittee shall maintain a file of all measurements, maintenance, reports and records for at least five years. This requirement is more stringent than 40 CFR Section 60.7(f), which specifies two years. [40 CFR 60.7(f), Minn. R , subp. 5(C), Minn. R , subp. 1] No owner or operator shall build, erect, install, or use any article, machine, equipment or process, the use of which conceals an emission which would otherwise constitute a violation of an applicable standard. [40 CFR 60.12, Minn. R ] EQUI 4 Solar mars Turbine S

21 Permit Issued: March 28, Permit Expires: Non-expiring Page 21 of 39 Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation The Permittee shall limit emissions of Nitrogen Oxides <= 25 parts per million at 15 percent oxygen, or 150 ng/j of useful output (1.2 lb/mwh). [40 CFR (a), 40 CFR pt. 60, Table 1, Minn. R ] The Permittee shall limit emissions of Sulfur Dioxide <= 110 nanograms per joule (0.90 lb/mwh) gross output. [40 CFR (a)(1), Minn. R ] Opacity <= 20 percent opacity once operating temperatures have been attained. [Minn. R , subp. 1] Sulfur Dioxide <= 0.50 pounds per million Btu heat input (The potential to emit from the unit is lb/mmbtu due to equipment design and allowable fuels). [Minn. R , subp. 2(A)] Sulfur Dioxide <= pounds per million Btu heat input This limit is effective on January 31, [Minn. R , subp. 2(B)] Sulfur Content of Fuel <= 0.09 percent by weight. The Permittee shall comply with this limit by complying with the sulfur monitoring requirements under 40 CFR pt. 60, subp. KKKK. [Minn. R , subp. 2, To avoid major source under 40 CFR 70.2 & Minn. R ] The Permittee is authorized to construct and operate EQUI 4 meeting the following design requirements, within 18 months after permit issuance of Permit No The unit shall meet all applicable requirements of this permit. Design Requirements; 16,696 horsepower/hour capacity. [Minn. R , subp. 2] Fuel type: Natural gas only. [Minn. R , subp. 35a] The Permittee shall keep records of fuel type and usage on a monthly basis. [Minn. R , subp. 5] The Permittee shall operate and maintain EQUI 4 stationary combustion turbine, air pollution control equipment, and monitoring equipment in a manner consistent with good air pollution control practices for minimizing emissions at all times including during startup, shutdown, and malfunction. [40 CFR , Minn. R ] The Permittee must conduct an initial performance test, as required in 40 CFR 60.8 for NOX. Subsequent NOX performance tests shall be conducted on an annual basis (no more than 14 calendar months following the previous performance test). See performance test for additional requirements. For each NOX performance test run, the Permittee shall measure the NOX and diluent gas concentrations, using either EPA Methods 7E and 3A, or EPA Method 20 in appendix A of 40 CFR pt. 60 to conduct performance tests. Concurrently measure the heat input to the unit, using a fuel flowmeter (or flowmeters), and measure the electrical and thermal output of

22 Permit Issued: March 28, Permit Expires: Non-expiring Page 22 of 39 Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation the unit. Use EPA Method 19 in appendix A of 40 CFR pt. 60 to calculate the NOX emission rate in lb/mmbtu. Then, use Equations 1 and, if necessary, 2 and 3 in 40 CFR (f) to calculate the NOX emission rate in lb/mwh. 40 CFR (f) equations are listed in Appendix B of this permit. [40 CFR (a)(1)(ii), Minn. R ] Calculate the hourly average NOX emission rates, in units of the emission standards under 40 CFR , using either ppm for units complying with the concentration limit or Equation 1 of 40 CFR (f) for units complying with the output based standard. For combined-cycle and combined heat and power complying with the output-based standard, use Equation 1 of 40 CFR (f), except that the gross energy output is calculated as the sum of the total electrical and mechanical energy generated by the combustion turbine, the additional electrical or mechanical energy (if any) generated by the steam turbine following the heat recovery steam generator, and 100 percent of the total useful thermal energy output that is not used to generate additional electricity or mechanical output, expressed in equivalent MW, as in the Equations 2 and 3 of 40 CFR (f). [40 CFR (f), Minn. R ] Sampling traverse points for NOX are to be selected following EPA Method 20 and sampled for equal time intervals. The sampling must be performed with a traversing single-hole probe, or, if feasible, with a stationary multi-hole probe that samples each of the points sequentially. Alternatively, a multihole probe designed and documented to sample equal volumes from each hole may be used to sample simultaneously at the required points. [40 CFR (a)(2), Minn. R ] The Permittee must demonstrate compliance with the NOX emission limit in 40 CFR at each tested load level. Compliance is achieved if the three-run arithmetic average NOX emission rate at each tested level meets the applicable emission limit in 40 CFR [40 CFR (b)(4), Minn. R ] The NOX performance test must be done at any load condition within plus or minus 25 percent of 100 percent of peak load. The Permittee may perform testing at the highest achievable load point, if at least 75 percent of peak load cannot be achieved in practice. The Permittee must conduct three separate test runs for each performance test. The minimum time per run is 20 minutes. [40 CFR (b), Minn. R ] The ambient temperature must be greater than 0 F during the NOX performance test. [40 CFR (b)(6), Minn. R ] (a) The Permittee must conduct an initial performance test, as required in 40 CFR 60.8 for SO2. Subsequent SO2 performance tests shall be conducted on an annual basis (no more than 14

23 Permit Issued: March 28, Permit Expires: Non-expiring Page 23 of 39 Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation calendar months following the previous performance test). (1) The Permittee shall periodically determine the sulfur content of the fuel combusted in the turbine, therefore a representative fuel sample shall be collected following ASTM D5287 (incorporated by reference, see 40 CFR 60.17) for natural gas to conduct SO2 performance tests. The fuel analyses of 40 CFR may be performed either by the Permittee, a service contractor retained by the Permittee, the fuel vendor, or any other qualified agency. Analyze the samples for the total sulfur content of the fuel using: (ii) For gaseous fuels, ASTM D1072, or alternatively D3246, D4084, D4468, D4810, D6228, D6667, or Gas Processors Association Standard 2377 (all of which are incorporated by reference, see 40 CFR 60.17). [40 CFR , Minn. R ] The Permittee shall monitor the total sulfur content of the fuel being fired in the turbine. The sulfur content of the fuel must be determined using total sulfur methods described in 40 CFR Alternatively, if the total sulfur content of the gaseous fuel during the most recent performance test was less than half the applicable limit, ASTM D4084, D4810, D5504, or D6228, or Gas Processors Association Standard 2377 (all of which are incorporated by reference, see 40 CFR 60.17), which measure the major sulfur compounds, may be used. [40 CFR , Minn. R ] (i) The Permittee shall maintain daily total sulfur content measurements for 30 consecutive unit operating days, using the applicable methods specified in 40 CFR pt. 60 subp. KKKK. Based on the results of the 30 daily samples, the required frequency for subsequent monitoring of the fuel's total sulfur content shall be as specified in 40 CFR (c)(1)(ii), (iii), or (iv), as applicable. (ii) If none of the 30 daily measurements of the fuel's total sulfur content exceeds half the applicable standard, subsequent sulfur content monitoring may be performed at 12-month intervals. If any of the samples taken at 12-month intervals has a total sulfur content greater than half but less than the applicable limit, follow the procedures in 40 CFR (c)(1)(iii). If any measurement exceeds the applicable limit, follow the procedures in 40 CFR (c)(1)(iv). (iii) If at least one of the 30 daily measurements of the fuel's total sulfur content is greater than half but less than the applicable limit, but none exceeds the applicable limit, then: (A) The Permittee shall collect and analyze a sample every 30 days for 3 months. If any sulfur content measurement exceeds the applicable limit, follow the procedures in 40 CFR (c)(1)(iv). Otherwise, follow the procedures in 40 CFR

24 Permit Issued: March 28, Permit Expires: Non-expiring Page 24 of 39 Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation (c)(1)(iii)(B). (B) Begin monitoring at 6-month intervals for 12 months. If any sulfur content measurement exceeds the applicable limit, follow the procedures in 40 CFR (c)(1)(iv). Otherwise, follow the procedures in 40 CFR (c)(1)(iii)(C). (C) Begin monitoring at 12-month intervals. If any sulfur content measurement exceeds the applicable limit, follow the procedures in 40 CFR (c)(1)(iv). Otherwise, continue to monitor at this frequency. (iv) If a sulfur content measurement exceeds the applicable limit, immediately begin daily monitoring according to 40 CFR (c)(1)(i). Daily monitoring shall continue until 30 consecutive daily samples, each having a sulfur content no greater than the applicable limit, are obtained. At that point, the applicable procedures of 40 CFR (c)(1)(ii) or (iii) of this section shall be followed. [40 CFR (c)(1), Minn. R ] The Permittee shall submit reports of excess emissions and monitor downtime, in accordance with 40 CFR 60.7(c) for EQUI 4 that requires the Permittee to periodically determine the fuel sulfur content. Excess emissions must be reported for all periods of unit operation, including start-up, shutdown, and malfunction. [40 CFR (a), Minn. R ] The Permittee shall submit a written report of the results of each performance test before the close of business on the 60th day following the completion of the performance test. [40 CFR (b), Minn. R ] Excess emissions and monitoring downtime for monitoring the sulfur content of fuel are defined as follows: (a) For samples of gaseous fuel and for oil samples obtained using daily sampling, flow proportional sampling, or sampling from the unit's storage tank, an excess emission occurs each unit operating hour included in the period beginning on the date and hour of any sample for which the sulfur content of the fuel being fired in the combustion turbine exceeds the applicable limit and ending on the date and hour that a subsequent sample is taken that demonstrates compliance with the sulfur limit. (c) A period of monitor downtime begins when a required sample is not taken by its due date. A period of monitor downtime also begins on the date and hour of a required sample, if invalid results are obtained. The period of monitor downtime ends on the date and hour of the next valid sample. [40 CFR , Minn. R ] The Permittee shall submit a notification of any physical or operational change which increases emission rate: due 60 days (or as soon as practical) before the change is commenced. [40

25 Permit Issued: March 28, Permit Expires: Non-expiring Page 25 of 39 Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation CFR 60.7(a)(4), Minn. R , subp. 1] Recordkeeping: The Permittee shall maintain records of the occurrence and duration of any startup, shutdown, or malfunction in the operation of the facility including; any malfunction of the air pollution control equipment; or any periods during which a continuous monitoring system or monitoring device is inoperative. [40 CFR 60.7(b), Minn. R , subp. 1] Recordkeeping: The Permittee shall maintain a file of all measurements, maintenance, reports and records for at least five years. This requirement is more stringent than 40 CFR Section 60.7(f), which specifies two years. [40 CFR 60.7(f), Minn. R , subp. 5(C), Minn. R , subp. 1] No owner or operator shall build, erect, install, or use any article, machine, equipment or process, the use of which conceals an emission which would otherwise constitute a violation of an applicable standard. [40 CFR 60.12, Minn. R ] EQUI 5 Reciprocating IC Engine The Permittee shall limit emissions of Nitrogen Oxides <= 2.0 grams per horsepower-hour. [40 CFR (e), 40 CFR (c), 40 CFR pt. 60, subp. JJJJ, Table 1, Minn. R , Minn. R ] The Permittee shall limit emissions of Carbon Monoxide <= 4.0 grams per horsepower-hour. [40 CFR (e), 40 CFR (c), 40 CFR pt. 60, subp. JJJJ, Table 1, Minn. R , Minn. R ] The Permittee shall limit emissions of Volatile Organic Compounds <= 1.0 grams per horsepower-hour. [40 CFR (e), 40 CFR (c), 40 CFR pt. 60, subp. JJJJ, Table 1, Minn. R , Minn. R ] Opacity <= 20 percent opacity once operating temperatures have been attained. [Minn. R , subp. 1] Sulfur Dioxide <= 0.50 pounds per million Btu heat input. The potential to emit from the unit is lb/mmbtu due to equipment design and allowable fuels. [Minn. R , subp. 2(A)] Sulfur Dioxide <= pounds per million Btu heat input. This limit is effective on January 31, The potential to emit from the unit is lb/mmbtu due to equipment design and allowable fuels. [Minn. R , subp. 2(B)] The Permittee is authorized to construct and operate EQUI 5 meeting the following design requirements, within 18 months after permit issuance of Permit No The unit shall meet all applicable requirements of this permit. Design Requirements: 1,102 brake horsepower/hour SI-4SLB firing method. [Minn. R , subp. 2]

26 Permit Issued: March 28, Permit Expires: Non-expiring Page 26 of 39 Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation Fuel type: Natural gas only. [Minn. R , subp. 35a] Hours of Operation: The Permittee shall maintain documentation on site that the unit is an emergency generator by design that qualifies under the U.S. EPA memorandum entitled "Calculating Potential to Emit (PTE) for Emergency Generators" dated September 6, 1995, limiting operation to 500 hours per year. [Minn. R , subps. 4-5] The Permittee shall keep records of fuel type and usage on a monthly basis. [Minn. R , subp. 5] EQUI 5 is a new stationary RICE located at an area source and the Permittee must meet the requirements of 40 CFR pt. 63, subp. ZZZZ by meeting the requirements of 40 CFR pt. 60 subp. IIII, for compression ignition engines or 40 CFR pt. 60 subp. JJJJ, for spark ignition engines. No further requirements apply for such engines under 40 CFR pt. 63, subp. ZZZZ. [40 CFR (c)(1), Minn. R ] The Permittee is an owner and operator of EQUI 5 that is an emergency stationary SI ICE with a maximum engine power greater than 19 KW (25 HP) that commenced construction after June 12, 2006, and was manufactured on or after January 1, [40 CFR (a)(4), 40 CFR (c), Minn. R , Minn. R ] The Permittee shall not install engines that do not meet the applicable requirements in 40 CFR after January 1, [40 CFR (c), 40 CFR (c), Minn. R , Minn. R ] The Permittee must install a non-resettable hour meter. [40 CFR (a), 40 CFR (c), Minn. R , Minn. R ] The Permittee must operate and maintain EQUI 5 that achieves the emission standards as required in 40 CFR over the entire life of the engine. [40 CFR , 40 CFR (c), Minn. R , Minn. R ] The Permittee must operate EQUI 5 according to the requirements in 40 CFR (d)(1) through (3). In order for the engine to be considered an emergency stationary ICE under 40 CFR pt. 60, subp. JJJJ, 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 40 CFR (d)(1) through (3), is prohibited. If the Permittee does not operate the engine according to the requirements in 40 CFR (d)(1) through (3), the engine will not be considered an emergency engine under 40 CFR pt. 60, subp. JJJJ and must meet all requirements for non-emergency engines. (1) There is no time limit on the use of emergency stationary ICE in emergency situations. (2) The Permittee may operate EQUI 5 for any combination of the purposes specified in 40 CFR (d)(2)(i) through (iii)

27 Permit Issued: March 28, Permit Expires: Non-expiring Page 27 of 39 Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation for a maximum of 100 hours per calendar year. Any operation for non-emergency situations as allowed by 40 CFR (d)(3) counts as part of the 100 hours per calendar year allowed by 40 CFR (d)(2). (i) EQUI 5 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 ICE beyond 100 hours per calendar year. (3) EQUI 5 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 in 40 CFR (d)(2). Except as provided in 40 CFR (d)(3)(i), 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. (i) 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 identifies and records 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

28 Permit Issued: March 28, Permit Expires: Non-expiring Page 28 of 39 Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation balancing authority or local transmission and distribution system operator may keep these records on behalf of the Permittee. [40 CFR (d), 40 CFR (c), Minn. R , Minn. R ] The Permittee is purchasing a non-certified engine that must demonstrate compliance with the emission standards specified in 40 CFR (d), according to the requirements specified in 40 CFR , as applicable, and according to 40 CFR (b)(2)(ii). The Permittee must keep a maintenance plan and records of conducted maintenance and must, to the extent practicable, maintain and operate the engine in a manner consistent with good air pollution control practice for minimizing emissions. In addition, the Permittee must conduct an initial performance test and conduct subsequent performance testing every 8,760 hours or 3 years, whichever comes first, thereafter to demonstrate compliance. [40 CFR (b)(2)(ii), 40 CFR (c), Minn. R , Minn. R ] (a) Each performance test must be conducted within 10 percent of 100 percent peak (or the highest achievable) load and according to the requirements in 40 CFR 60.8 and under the specific conditions that are specified by 40 CFR pt. 60, subp. JJJJ, Table 2. (b) The Permittee shall not conduct performance tests during periods of startup, shutdown, or malfunction, as specified in 40 CFR 60.8(c). If EQUI 5 is non-operational, the Permittee does not need to startup the engine solely to conduct a performance test; however, the Permittee must conduct the performance test immediately upon startup of the engine. (c) The Permittee must conduct three separate test runs for each performance test required in 40 CFR , as specified in 40 CFR 60.8(f). Each test run must be conducted within 10 percent of 100 percent peak (or the highest achievable) load and last at least 1 hour. (d) To determine compliance with the NOX mass per unit output emission limitation, convert the concentration of NOX in the engine exhaust using Equation 1 of 40 CFR (Appendix C of this permit). (e) To determine compliance with the CO mass per unit output emission limitation, convert the concentration of CO in the engine exhaust using Equation 2 of 40 CFR (Appendix C of this permit). (f) For purposes of 40 CFR pt. 60, subp. JJJJ, when calculating emissions of VOC, emissions of formaldehyde should not be included. To determine compliance with the VOC mass per unit output emission limitation, convert the concentration of VOC

29 Permit Issued: March 28, Permit Expires: Non-expiring Page 29 of 39 Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation in the engine exhaust using Equation 3 of 40 CFR (Appendix C of this permit). (g) If the Permittee chooses to measure VOC emissions using either Method 18 of 40 CFR pt. 60, appendix A, or Method 320 of 40 CFR pt. 63, appendix A, then the Permittee has the option of correcting the measured VOC emissions to account for the potential differences in measured values between these methods and Method 25A. The results from Method 18 and Method 320 can be corrected for response factor differences using Equations 4 and 5 of 40 CFR (Appendix C of this permit). [40 CFR , 40 CFR (c), Minn. R , Minn. R ] The Permittee must submit a copy of each performance test as conducted in 40 CFR within 60 days after the test has been completed. Performance test reports using EPA Method 18, EPA Method 320, or ASTM D (incorporated by reference-see 40 CFR 60.17) to measure VOC require reporting of all QA/QC data. For Method 18, report results from sections 8.4 and ; for Method 320, report results from sections 8.6.2, 9.0, and 13.0; and for ASTM D report results of all QA/QC procedures in Annexes 1-7. [40 CFR (d), 40 CFR (c), Minn. R , Minn. R ] The Permittee must keep the following records of the information: (1) All notifications submitted to comply with 40 CFR pt. 60, subp. JJJJ and all documentation supporting any notification. (2) Maintenance conducted on the engine. (4) Documentation that the engine meets the emission standards. [40 CFR (a), 40 CFR (c), Minn. R , Minn. R ] The Permittee must submit an initial notification as required in 40 CFR 60.7(a)(1). The notification must include the information below: (1) Name and address of the Permittee; (2) The address of the affected source; (3) Engine information including make, model, engine family, serial number, model year, maximum engine power, and engine displacement; (4) Emission control equipment; and (5) Fuel used. [40 CFR (c), 40 CFR (c), Minn. R , Minn. R ] The Permittee shall submit a notification of any physical or operational change which increases emission rate: due 60 days

30 Permit Issued: March 28, Permit Expires: Non-expiring Page 30 of 39 Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation (or as soon as practical) before the change is commenced. [40 CFR 60.7(a)(4), Minn. R , subp. 1] Recordkeeping: The Permittee shall maintain records of the occurrence and duration of any startup, shutdown, or malfunction in the operation of the facility including; any malfunction of the air pollution control equipment; or any periods during which a continuous monitoring system or monitoring device is inoperative. [40 CFR 60.7(b), Minn. R , subp. 1] Recordkeeping: The Permittee shall maintain a file of all measurements, maintenance, reports and records for at least five years. This requirement is more stringent than 40 CFR Section 60.7(f), which specifies two years. [40 CFR 60.7(f), Minn. R , subp. 5(C), Minn. R , subp. 1] No owner or operator shall build, erect, install, or use any article, machine, equipment or process, the use of which conceals an emission which would otherwise constitute a violation of an applicable standard. [40 CFR 60.12, Minn. R ] EQUI 6 Heater Particulate Matter <= 0.40 pounds per million Btu heat input (The potential to emit from the unit is lb/mmbtu due to equipment design and allowable fuels.). [Minn. R , subp. 1] Opacity <= 20 percent opacity except for one six-minute period per hour of not more than 60 percent opacity. [Minn. R , subp. 2] The Permittee is authorized to construct and operate EQUI 6 meeting the following design requirements, within 18 months after permit issuance of Permit No The unit shall meet all applicable requirements of this permit. Design Requirements; MMBtu/hr capacity. [Minn. R , subp. 2] EQUI 7 Heater Particulate Matter <= 0.40 pounds per million Btu heat input (The potential to emit from the unit is lb/mmbtu due to equipment design and allowable fuels.). [Minn. R , subp. 1] Opacity <= 20 percent opacity except for one six-minute period per hour of not more than 60 percent opacity. [Minn. R , subp. 2] The Permittee is authorized to construct and operate EQUI 7 meeting the following design requirements, within 18 months after permit issuance of Permit No The unit shall meet all applicable requirements of this permit. Design Requirements; MMBtu/hr capacity. [Minn. R , subp. 2]

31 Permit Issued: March 28, Permit Expires: Non-expiring Page 31 of 39 Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation 6. Submittal/action requirements This section lists most of the submittals required by this permit. Please note that some submittal requirements may appear in the Limits and Other Requirements section, or, if applicable, within a Compliance Schedule section. Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation TFAC Northern Natural Gas Co - Faribault The Permittee shall submit a semiannual deviations report : Due semiannually, by the 30th of January and July The first semiannual report submitted by the Permittee shall cover the calendar half-year in which the permit is issued. The first report of each calendar year covers January 1 - June 30. The second report of each calendar year covers July 1 - December 31. If no deviations have occurred, the Permittee shall submit the report stating no deviations. [Minn. R , subp. 6(A)(2)] The Permittee shall submit a compliance schedule progress report : Due semiannually, by the 30th of January and July The Compliance Schedule Progress Report shall contain the information specified in Minn. R , subp. 6(B) and shall be submitted on a form approved by the Commissioner in accordance with the Compliance Schedule contained in this permit. Progress Reports will not be needed upon completion of all activities contained in the Compliance Schedule. [Minn. R , subp. 6(B)] The Permittee shall submit a compliance certification : Due annually, by the 31st of January (for the previous calendar year). The Permittee shall submit this to the Commissioner on a form approved by the Commissioner. This report covers all deviations experienced during the calendar year. [Minn. R , subp. 6(C)] COMG 2 Limits to avoid Part The Permittee shall submit an annual report : Due annually, by the 31st of January The report shall document COMG 2 NOX and CO 12-month rolling sum calculations for the previous calendar year. The report shall be submitted with the annual Compliance Certification required by this permit. As part of the Annual Report, the Permittee shall verify and certify that the Facility has maintained minor source status for New Source Review. [Minn. R , subp. 2] EQUI 1 EU002 Emergency Generator The Permittee shall submit a notification of equipment removal/dismantlement: Due 15 calendar days after Equipment

32 Permit Issued: March 28, Permit Expires: Non-expiring Page 32 of 39 Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation Removal and/or Dismantlement Date. This notification shall specify which Subject Items (by ID#) were removed and on what date. [Minn. R , subp. 2] EQUI 2 EU001 Natural Gas Turbine Nitrogen Oxides : The Permittee shall conduct a performance test : Due after Permit Issuance Date every 60 months to measure emissions. The first test is due by the date specified and all subsequent tests are due by the end of each 60-month period following that date. The performance test shall be conducted at worst case conditions as defined at Minn. R , subp. 2, using EPA Reference Method 7E, or other method approved by MPCA in the performance test plan approval. Testing conducted during the 60 days prior to the performance test due date satisfies the performance test due date, and will not reset the test due date for future testing as required: 1) by this permit; 2) by the most recently approved Performance Test Frequency Plan; or 3) within a Notice of Compliance letter. Testing conducted more than two months prior to the performance test due date satisfies this test due date requirement and will reset the performance test due date. [Minn. R , subp. 1] Sulfur Content of Fuel : The Permittee shall submit an annual report : Due annually, by the 31st of January. The report shall document the sulfur monitoring analysis results for the previous calendar year. The report shall be submitted with the annual Compliance Certification required by this permit. [Minn. R , subp. 2] EQUI 4 Solar mars Turbine S Nitrogen Oxides : As required in 40 CFR 60.8, the Permittee shall conduct an initial performance test within 60 days after achieving the maximum production rate at which the facility will be operated, but no later the Permittee shall conduct an initial performance test : Due 180 calendar days after Initial Startup Date. The performance test shall be conducted at worst case conditions as defined at Minn. R , subp. 2, using EPA Reference Method 20, or other method approved by MPCA in the performance test plan approval. [40 CFR (a), Minn. R ] Nitrogen Oxides : The Permittee shall conduct a performance test : Due annually, but no more than 14 months following the previous performance test. The performance test shall be conducted at worst case conditions as defined at Minn. R , subp. 2, using EPA Reference Method 20, or other

33 Permit Issued: March 28, Permit Expires: Non-expiring Page 33 of 39 Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation method approved by MPCA in the performance test plan approval. The Permittee is not using water or steam injection to control NOX emissions. If the NOX emission result from the performance test is less than or equal to 75 percent of the NOX emission limit for the turbine, the Permittee may reduce the frequency of subsequent performance tests to once every 2 years (no more than 26 calendar months following the previous performance test). If the results of any subsequent performance test exceed 75 percent of the NOX emission limit for the turbine, the Permittee must resume annual performance tests. [40 CFR , 40 CFR (a), Minn. R ] Sulfur Dioxide : As required in 40 CFR 60.8, the Permittee shall conduct an initial performance test within 60 days after achieving the maximum production rate at which the facility will be operated, but no later the Permittee shall conduct an initial performance test : Due 180 calendar days after Initial Startup Date The performance test shall be conducted at worst case conditions as defined at Minn. R , subp. 2, using EPA Reference Method 20, or other method approved by MPCA in the performance test plan approval. [40 CFR (a), Minn. R ] Sulfur Dioxide : The Permittee shall conduct a performance test : Due annually, but no more than 14 months following the previous performance test. The performance test shall be conducted at worst case conditions as defined at Minn. R , subp. 2, using EPA Reference Method 20, or other method approved by MPCA in the performance test plan approval. [40 CFR (a), Minn. R ] The Permittee shall submit a notification of date construction began: Due 30 calendar days after Date of Construction Start. Submit the name and number of the Subject Item and the date construction began. [40 CFR 60.7(a)(1), Minn. R , subp. 16(L), Minn. R , subp. 1] The Permittee shall submit a notification of the actual date of initial startup: Due 15 calendar days after Initial Startup Date. Submit the name and number of the Subject Item and the date of startup. Startup is as defined in Minn. R , subp. 42a. [40 CFR 60.7(a)(3), Minn. R , subp. 16(L), Minn. R , subp. 1] Sulfur Content of Fuel : The Permittee shall submit an annual report : Due annually, by the 31st of January. The report shall document the sulfur monitoring analysis results for the previous calendar year. The report shall be submitted with the annual Compliance Certification required by this permit. [Minn. R , subp. 2] EQUI 5 Reciprocating IC

34 Permit Issued: March 28, Permit Expires: Non-expiring Page 34 of 39 Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation Engine Nitrogen Oxides : As required in 40 CFR 60.8, the Permittee shall conduct an initial performance test within 60 days after achieving the maximum production rate at which the facility will be operated, but no later the Permittee shall conduct an initial performance test : Due 180 calendar days after Initial Startup Date. The performance test shall be conducted at worst case conditions as defined at Minn. R , subp. 2, using EPA Reference Method 20, or other method approved by MPCA in the performance test plan approval. [40 CFR (b)(2)(ii), 40 CFR (c), Minn. R , Minn. R , Minn. R ] Nitrogen Oxides : Whichever comes first, the Permittee shall conduct a performance test every 8,760 hours or conduct a performance test : Due after Initial Performance Test Date every 36 months. The performance test shall be conducted at worst case conditions as defined at Minn. R , subp. 2, using EPA Reference Method 20, or other method approved by MPCA in the performance test plan approval. [40 CFR (b)(2)(ii), 40 CFR (c), Minn. R , Minn. R , Minn. R ] Carbon Monoxide : As required in 40 CFR 60.8, the Permittee shall conduct an initial performance test within 60 days after achieving the maximum production rate at which the facility will be operated, but no later the Permittee shall conduct an initial performance test : Due 180 calendar days after Initial Startup Date. The performance test shall be conducted at worst case conditions as defined at Minn. R , subp. 2, using EPA Reference Method 10, or other method approved by MPCA in the performance test plan approval. [40 CFR (b)(2)(ii), 40 CFR (c), Minn. R , Minn. R , Minn. R , subp. 1] Carbon Monoxide : Whichever comes first, the Permittee shall conduct a performance test every 8,760 hours or conduct a performance test : Due after Initial Performance Test Date every 36 months. The performance test shall be conducted at worst case conditions as defined at Minn. R , subp. 2, using EPA Reference Method 10, or other method approved by MPCA in the performance test plan approval. [40 CFR (b)(2)(ii), 40 CFR (c), Minn. R , Minn. R , Minn. R , subp. 1] Volatile Organic Compounds : As required in 40 CFR 60.8, the Permittee shall conduct an initial performance test within 60 days after achieving the maximum production rate at which the facility will be operated, but no later the Permittee shall conduct an initial performance test : Due 180 calendar days after Initial Startup Date. The performance test shall be conducted at worst case conditions as defined at Minn. R , subp. 2, using EPA Reference Method 18, 25A, and 320, or other method approved by MPCA in the performance test plan approval. [40 CFR (b)(2)(ii), 40 CFR (c), Minn. R , Minn. R , Minn. R ,

35 Permit Issued: March 28, Permit Expires: Non-expiring Page 35 of 39 Subject Item Sec.SI.Reqt SI des:si desc Requirement & Citation subp. 1] Volatile Organic Compounds : Whichever comes first, the Permittee shall conduct a performance test every 8,760 hours or conduct a performance test : Due after Initial Performance Test Date every 36 months. The performance test shall be conducted at worst case conditions as defined at Minn. R , subp. 2, using EPA Reference Method 18, 25A, and 320, or other method approved by MPCA in the performance test plan approval. [40 CFR (b)(2)(ii), 40 CFR (c), Minn. R , Minn. R , Minn. R , subp. 1] The Permittee shall submit a notification of date construction began: Due 30 calendar days after Date of Construction Start. Submit the name and number of the Subject Item and the date construction began. [40 CFR 60.7(a)(1), Minn. R , subp. 16(L), Minn. R , subp. 1] The Permittee shall submit a notification of the actual date of initial startup: Due 15 calendar days after Initial Startup Date. Submit the name and number of the Subject Item and the date of startup. Startup is as defined in Minn. R , subp. 42a. [40 CFR 60.7(a)(3), Minn. R , subp. 16(L), Minn. R , subp. 1] 7. Appendices Appendix A. Equations for COMG 2 These emission factors, capacities, and equations are used in the compliance demonstration method for the limits in COMG 2. Emission Factors: Pollutant Ambient Temperature > 0 F Ambient Temperature < 0 F (grams/hp-hr) (grams/hp-hr) CO NOx Capacities: Emission Ambient Temperature > 0 F Ambient Temperature < 0 F Unit (Hp) (Hp) EQUI 2 16,490 16,966 EQUI 4 16,427 16,969

36 Permit Issued: March 28, Permit Expires: Non-expiring Page 36 of 39 Monthly Emission Calculations: E = SUM[((EF A * C A/453)*(H A/2000)) + ((EF B * C B/453)*(H B/2000))] where: E = emissions of pollutant (CO, NOX) EF A = temperature-specific emission factor for the pollutant when ambient temperatures are equal to or greater than 0 F C A = temperature-specific capacity for the emission unit (EQUI 2, EQUI 4) when ambient temperatures are equal to or greater than 0 F H A = hours operated when ambient temperatures are equal to or greater than 0 F EF B = temperature-specific emission factor for the pollutant when ambient temperatures are less than 0 F C B = temperature-specific capacity for the emission unit (EQUI 2, EQUI 4) when ambient temperatures are less than 0 F H B = hours of operation when ambient temperatures are less than 0 F Appendix B. Emission Calculations for EQUI 4 40 CFR (f) (1) For simple-cycle operation: (Eq. 1) Where: E = hourly NOX emission rate, in lb/mwh, (NOX) h = hourly NOX emission rate, in lb/mmbtu, EE = (NNNN XX) h (HHHH) h PP (HI) h = hourly heat input rate to the unit, in MMBtu/h, measured using the fuel flowmeter(s), e.g., calculated using Equation D-15a in appendix D to 40 CFR pt. 75, and P = gross energy output of the combustion turbine in MW. (2) For combined-cycle and combined heat and power complying with the output-based standard, use Equation 1, except that the gross energy output is calculated as the sum of the total electrical and mechanical energy generated by the combustion turbine, the additional electrical or mechanical energy (if any) generated by the steam turbine following the heat recovery steam generator, and 100 percent of the total useful thermal energy output that is not used to generate additional electricity or mechanical output, expressed in equivalent MW, as in the following equations:

37 Permit Issued: March 28, Permit Expires: Non-expiring Page 37 of 39 (Eq. 2) Where: PP = (PPPP) tt + (PPPP) cc + PPPP = PPPP P = gross energy output of the stationary combustion turbine system in MW. (Pe) t = electrical or mechanical energy output of the combustion turbine in MW, (Pe) c = electrical or mechanical energy output (if any) of the steam turbine in MW, and (Eq. 3) Where: PPPP = QQ HH BBBBBB/MMMMh Ps = useful thermal energy of the steam, measured relative to ISO conditions, not used to generate additional electric or mechanical output, in MW, Q = measured steam flow rate in lb/h, H = enthalpy of the steam at measured temperature and pressure relative to ISO conditions, in Btu/lb, and = conversion from Btu/h to MW. Po = other useful heat recovery, measured relative to ISO conditions, not used for steam generation or performance enhancement of the combustion turbine Appendix C. Emission Calculations for EQUI 5 40 CFR (d) To determine compliance with the NO X mass per unit output emission limitation, convert the concentration of NO X in the engine exhaust using Equation 1: (Eq. 1) Where: EEEE = CC dd QQ TT HHHH hrr

38 Permit Issued: March 28, Permit Expires: Non-expiring Page 38 of 39 ER = Emission rate of NO X in g/hp-hr. C d = Measured NO X concentration in parts per million by volume (ppmv) = Conversion constant for ppm NO X to grams per standard cubic meter at 20 degrees Celsius. Q = Stack gas volumetric flow rate, in standard cubic meter per hour, dry basis. T = Time of test run, in hours. HP-hr = Brake work of the engine, horsepower-hour (HP-hr). (e) To determine compliance with the CO mass per unit output emission limitation, convert the concentration of CO in the engine exhaust using Equation 2: (Eq. 2) Where: ER = Emission rate of CO in g/hp-hr. C d = Measured CO concentration in ppmv. EEEE = CC dd QQ TT HHHH hrr = Conversion constant for ppm CO to grams per standard cubic meter at 20 degrees Celsius. Q = Stack gas volumetric flow rate, in standard cubic meters per hour, dry basis. T = Time of test run, in hours. HP-hr = Brake work of the engine, in HP-hr. (f) When calculating emissions of VOC, emissions of formaldehyde should not be included. To determine compliance with the VOC mass per unit output emission limitation, convert the concentration of VOC in the engine exhaust using Equation 3: (Eq. 3) Where: ER = Emission rate of VOC in g/hp-hr. EEEE = CC dd QQ TT HHHH hrr

39 Permit Issued: March 28, Permit Expires: Non-expiring Page 39 of 39 C d = VOC concentration measured as propane in ppmv = Conversion constant for ppm VOC measured as propane, to grams per standard cubic meter at 20 degrees Celsius. Q = Stack gas volumetric flow rate, in standard cubic meters per hour, dry basis. T = Time of test run, in hours. HP-hr = Brake work of the engine, in HP-hr. (g) If the Permittee chooses to measure VOC emissions using either Method 18 of 40 CFR pt. 60, appendix A, or Method 320 of 40 CFR pt. 63, appendix A, then the Permittee has the option of correcting the measured VOC emissions to account for the potential differences in measured values between these methods and Method 25A. The results from Method 18 and Method 320 can be corrected for response factor differences using Equations 4 and 5. (Eq. 4) Where: RRRR ii = CC MMMM CC AAAA RF i = Response factor of compound i when measured with EPA Method 25A. C Mi = Measured concentration of compound i in ppmv as carbon. C Ai = True concentration of compound i in ppmv as carbon. (Eq. 5) Where: CC iiiiiiiiii = RRRR ii CC iiiiiiiiii C icorr = Concentration of compound i corrected to the value that would have been measured by EPA Method 25A, ppmv as carbon. C imeas = Concentration of compound i measured by EPA Method 320, ppmv as carbon.

40 Technical Support Document For Air Emission Permit No 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 , subp. 1). The purpose of this document is to provide the legal and factual justification for each applicable requirement or policy decision considered in the preliminary determination to issue the permit. 1. General information 1.1 Applicant and stationary source location: Table 1. Applicant and source address Applicant/Address Northern Natural Gas Co rd St S Omaha, Nebraska Contact: Kelly Henry Phone: Stationary source/address (SIC Code: 4922) Northern Natural Gas Co - Faribault Compressor Canby Ave Faribault MN Facility description Northern Natural Gas Co - Faribault Compressor (NNG or Facility) is a natural gas compressor station located in Faribault, Minnesota. Compressor stations compress natural gas to a specified pressure along natural gas pipelines allowing the gas to continue moving through the pipeline to an intended recipient. The main contributing sources of air pollution include nitrogen oxides (NO X), carbon monoxide (CO), and sulfur dioxide (SO 2). 1.3 Description of the activities allowed by this permit action This permit action is Major Amendment for construction of a turbine (EQUI 4), an emergency generator (EQUI 5) to replace diesel emergency engine (EQUI 1), and two process heaters (EQUI 6 and 7). With the addition of the new emission units, the facility potential to emit (PTE) for NO X, CO, and SO 2 exceeds Part 70 permit thresholds. Limits on emissions of NO X, CO, and fuel sulfur content to limit SO 2 have been incorporated into the permit so that NNG is a Part 70 synthetic minor source. The MPCA has a combined operating and construction permitting program under Minn. R. ch. 7007, and under Minn. R Under that authority, this permit action authorizes construction. 1.4 Facility emissions: Table 2. Title I emissions summary Unlimited potential emissions from the modification tons per year (tpy) Limited potential emissions from the modification (tpy) NSR/112(g) threshold for new major source (tpy) Pollutant PM No PM No PM No NSR/112(g) review required? (yes/no) Technical Support Document, Permit Number: Page 1 of 8

41 Unlimited potential emissions from the modification tons per year (tpy) Limited potential emissions from the modification (tpy) NSR/112(g) threshold for new major source (tpy) NSR/112(g) review required? (yes/no) Pollutant NOX No SO No CO No Ozone (VOC) No Lead No CO2e* 66,019 66,019 75,000 No Single HAP No Total HAPs No *Carbon dioxide equivalents as defined in Minn. R For CO2e, the existing minor NSR source has a CO2e PTE less than 100,000 tpy, but with the modification the facility CO2e PTE is greater than 100,000 tpy. See sections 2.1 and 2.2 in the TSD where CO2e major/minor applicability is discussed. 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 , Total Facility Actual Emissions (2014) * * * 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 1.5 Changes to permit The MPCA has a combined operating and construction permitting program under Minnesota Rules Chapter 7007, and under Minn. R , the MPCA has authority to include additional requirements in a permit. Under that authority, the following changes to the permit are made through this permit action: updates to reflect current MPCA templates and standard citation formatting; completed requirements under SV 001 (STRU 1) and EU 001 (EQUI 2) including initial performance testing have been deleted (see Attachment 6 to this TSD for performance testing report); requirements listed under SV 001 (STRU 1) have been moved and are now listed under EQUI 2; reoccurring performance testing for EQUI 2 is required to be completed every 60 months because the initial performance test resulted in NO X emissions of % by volume at 15% oxygen, the test result is 26% of the limit, % by volume at 15% oxygen; and NESHAP 40 CFR pt. 63, subp. ZZZZ requirements have been incorporated into the permit for EQUI Regulatory and/or statutory basis Technical Support Document, Permit Number: Page 2 of 8

42 2.1 New source review (NSR) The existing facility potential to emit (PTE) is less than the major source thresholds for NSR (40 CFR 52.21(b)(1)). NNG has a PTE of 65,493 tpy CO 2e; and a PTE after the modification of 131,512 tpy CO 2e. The major source threshold is currently 100,000 tpy CO 2e. In a memo dated July 24, 2014 ( EPA discussed the June 23, 2014 Supreme Court ruling in Utility Air Regulatory Group v. EPA, addressing the application of stationary source permitting requirements for GHG emissions. The EPA stated that it will no longer apply or enforce the requirement to obtain a Prevention of Significant Deterioration (PSD) permit solely because a facility emits or has the potential to emit GHG above major source thresholds. The facility does not require a PSD permit for any pollutant other than CO 2e, therefore consistent with the Utility Air Regulatory Group decision; the MPCA will not require the Facility to obtain a PSD permit. Therefore, NNG is a minor source for NSR. 2.2 Part 70 permit program This permit establishes limits so that NNG is a nonmajor source under the Part 70 permit program. In the EPA memo referenced in the section above, EPA also stated that it will no longer apply or enforce the requirement to obtain a title V (Part 70) permit solely because a facility emits or has the potential to emit GHG above major source thresholds. Minn. R , subps. 1 and 2 mirror the major source federal thresholds of 100,000 tpy CO2e. As a result of the June 23, 2014 Supreme Court ruling in Utility Air Regulatory Group v. EPA, the basis for requiring a Part 70 permit due solely to GHG emissions no longer applies. All other regulated pollutants are below State Permitting thresholds. Therefore, at this time the facility is allowed to maintain a State Operating Permit. 2.3 New source performance standards (NSPS) The New Source Performance Standards for Stationary Gas Turbines (40 CFR pt. 60, subp. GG) applies to EQUI 2 which is a stationary gas turbine with a heat input at peak load equal to or greater than 10 million Btu (MMBtu) per hour, based on the lower heating value of the fuel fired, and commenced construction after October 3, The New Source Performance Standards for Stationary Combustion Turbines (40 CFR pt. 60, subp. KKKK) applies to EQUI 4 which is a stationary combustion turbine with a heat input at peak load equal to or greater than 10 MMBtu per hour, based on the higher heating value of the fuel, and commenced construction after February 18th, The New Source Performance Standards for Stationary Spark Ignition Internal Combustion Engines (40 CFR pt. 60, subp. JJJJ) applies to EQUI 5 which is an emergency stationary SI ICE with a maximum engine power greater than 19 KW (25 Hp) that commenced construction after June 12, 2006, and was manufactured on or after January 1, National emission standards for hazardous air pollutants (NESHAP) National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (40 CFR pt. 63, subp. ZZZZ) applies to EQUIs 1 and 5. NNG is an area source for NESHAPs. 2.5 Compliance assurance monitoring (CAM) CAM does not apply to NNG. CAM only applies at sources required to obtain a permit under 40 CFR pt Environmental review and air emissions risk analysis (AERA) The proposed modification is not subject to environmental review, i.e. an Environmental Assessment Worksheet (EAW), and is not required to perform an Air Emissions Risk Analysis (AERA). Technical Support Document, Permit Number: Page 3 of 8

43 2.9 Minnesota state rules Portions of the facility are subject to the following Minnesota Standards of Performance: Minn. R Standards of Performance for Stationary Internal Combustion Engines Minn. R Standards of Performance for Indirect Heating Fossil-Fuel-Burning Equipment Table 5. Regulatory overview of units affected by the modification/permit amendment Subject item* Applicable regulations Rationale COMG 2 (Limits to avoid Part 70) EQUI 1 (Emergency Generator) Limits to avoid major source classification under 40 CFR CFR pt. 63, subp. ZZZZ Minn. R Limits to avoid major source classification under 40 CFR 70.2 Part 70 Permit Limits on NOX and CO emissions to remain below 40 CFR 70.2 thresholds National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (RICE); the engine is an existing emergency compression ignition stationary RICE less than 500 Hp and construction commenced before June 12, 2006 Standards of Performance for Stationary Internal Combustion Engines Part 70 Permit Limits on fuel sulfur content to limit SO2 emissions to remain below 40 CFR 70.2 thresholds EQUI 2 (Natural Gas Turbine) 40 CFR pt. 60, subp. GG New Source Performance Standards for Stationary Gas Turbines Standards of Performance for Stationary Internal Combustion Minn. R Engines Limits to avoid major source classification under 40 CFR Part 70 Permit Limits on fuel sulfur content to limit SO2 emissions to 70.2 remain below 40 CFR 70.2 thresholds EQUI 4 (Solar mars Turbine S) EQUI 5 (Reciprocating IC engine) EQUI 6 40 CFR pt. 60, subp. KKKK Minn. R CFR pt. 63, subp. ZZZZ 40 CFR pt. 60, subp. JJJJ Minn. R New Source Performance Standards for Stationary Combustion Turbines Standards of Performance for Stationary Internal Combustion Engines National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (RICE); the engine is a new emergency spark ignition stationary RICE greater than 500 Hp and construction commenced after June 12, 2006 New Source Performance Standards for Stationary Spark Ignition Internal Combustion Engines Standards of Performance for Stationary Internal Combustion Engines (Heater 1) EQUI 7 (Heater 2) Minn. R Standards of Performance for Indirect Heating Fossil-Fuel-Burning Equipment *Location of the requirement in the permit (e.g., EQUI 1, STRU 2, etc.). 3. Technical information 3.1 Calculations of potential to emit Attachment 1 to this TSD contains a summary of the PTE of NNG and detailed spreadsheets and supporting information prepared by the MPCA and the Permittee. Emission factors for EQUIs 1 and 5 are based on AP- 42 and manufacturer data. Annual PTE from EQUIs 1 and 5 are based on 500 hours per year because these Technical Support Document, Permit Number: Page 4 of 8

44 are emergency generators. Emission factors for turbines EQUIs 2 and 4 are also based on AP-42 and manufacturer data. EQUIs 2 and 4 also have separate emissions factors and capable engine capacity when the turbines are operating in ambient temperatures that are above and below 0 F. Emission factors and engine capacity when temperatures are less than 0 F are worst case and are used to calculate hourly emissions. Annual average temperatures in Minnesota are above 0 F, therefore annual emissions are calculated using emissions factors for when temperatures are above 0 F. However, because of the difference in emission factors when temperatures are above or below 0 F, emissions that could potentially exceed 100 tons per year based on yearly temperatures are limited to prevent the facility from becoming a Part 70 source (NO X and CO emissions). All manufacturer data used to calculate emissions is listed under Attachment 5 to this TSD. The total facility emissions of SO 2 in the permit were calculated using the AP-42 Section 3.1, table 3.1-2a standard emission factor of lb/mmbtu. AP-42 also provides an emission factor equation; SO 2 in lb/mmbtu = 0.94*S, where S is the sulfur content in the fuel. AP-42 states that the SO 2 equation is more accurate than the standard emission factor of lb/mmbtu and the standard emission factor should be used if the sulfur content in the fuel is not available. EQUI 2 has a sulfur content of fuel limit of 0.8% by weight under 40 CFR pt. 60, subp. GG and is required to complete an analysis for fuel sulfur content of natural gas. EQUI 4 is also required to monitor the sulfur content of fuel under 40 CFR pt. 60, subp. KKKK. Therefore, calculating emissions using the SO 2 emission factor equation in AP-42 is appropriate. To ensure SO 2 emissions remain below Part 70 permitting thresholds, a sulfur content limit of 0.09% by weight is included in the permit for EQUIs 2 and 4. Previous sulfur monitoring records show that NNG will be able to meet a 0.09% by weight sulfur content limit (see Attachment 7 to this TSD). 3.2 Emission Unit Information EQUI 2 is an existing turbine. The permit and permit application for list EQUI 2 capacity as 16,000 Hp. Updated manufacturer information was provided to NNG (Attachment 5 to this TSD) that when operating at or above 0 degrees Fahrenheit (F), EQUI 2 has a capacity of 16,490 Hp, and when operating below 0 degrees F, EQUI 2 has a capacity of 16,966 Hp. Because the highest capacity the emission unit can operate is at 16,966 Hp, EQUI 2 s capacity has been updated to 16,966 Hp/hr in the MPCA s database, Tempo. EQUIs 2 and 4 are equipped with a manufacturer technology called SoLoNOx that is used to reduce NO X emissions. The technology utilizes lean-premixed combustion to ensure uniform air to fuel mixing to prevent NO X emissions from forming. EQUIs 2 and 4 are also equipped with PACO (pilot active control option) logic controls that allow the turbines to remain in SoLoNOx mode operation from 0 F down to -20 F and also enable the turbine to run at minimum pilot. Because the SoLoNOx technology and PACO logic controls are included as part of the turbine combustion system, SoLoNOx and PACO are not included as control equipment for this permit. 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. Technical Support Document, Permit Number: Page 5 of 8

45 The kind of monitoring found on similar units elsewhere. The table below summarizes the monitoring requirements associated with this amendment. Table 6. Monitoring Requirement (rule Subject item* basis) Monitoring Discussion COMG 2 (Limits to avoid Part 70) CO and NOX 90 tons per year, on a 12 month rolling basis (limits to avoid pt. 70) Recordkeeping: Daily records of hours of operation and ambient air temperature; Monthly calculations of emissions. reasonable. EQUI 1 (Emergency Generator) EQUI 2 (Natural Gas Turbine) EQUI 4 (Solar mars Turbine S) EQUI 5 (Reciprocating SO2: 0.50 lb/mmbtu; Opacity: 20 % (Minn. R ) Maintenance and Inspection Requirements (40 CFR pt. 63, subp. ZZZZ) NOX: % by volume at 15% O2; SO2: 0.015% by volume at 15% O2; Sulfur Content of Fuel: 0.8% by weight (40 CFR pt. 60, subp. GG) Sulfur Content of Fuel: 0.09% by weight (limits to avoid pt. 70) NOX: 25 ppm at 15% O2; SO2: 110 nanograms per joule; (40 CFR pt. 60, subp. KKKK) Sulfur Content of Fuel: 0.09% by weight (limits to avoid pt. 70) NOX: 2.0 gr/hphr; Recordkeeping: Fuel type and usage; fuel supplier certification Recordkeeping: hours of operation, operation and maintenance, certifications, and reports Recordkeeping: Performance testing for NOX, Sample analyses and fuel records for sulfur Recordkeeping: Sample analyses and fuel records for sulfur Recordkeeping: Performance testing for NOX, Sample analyses and fuel records for sulfur Recordkeeping: Sample analyses and fuel records for sulfur Recordkeeping: Performance testing for Records can be generated on a daily basis and can be completed using written logs. Emissions can then be calculated monthly. The likelihood of emissions exceeding limits when calculated daily is small, therefore 12-month rolling limits for NNG are This unit uses diesel and the manufacturer has certified emissions. The likelihood of violating either of the emission limits is very small. Since this is a permit condition, the semi-annual deviations report will document any deviations from the applicable conditions. Design based PTE for SO2, using manufacturer data, is 0.20 lb/mmbtu compared to the rule limit of 0.50 lb/mmbtu. Monitoring based on the National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines is adequate to demonstrate compliance. Monitoring based on the New Source Performance Standards for Stationary Gas Turbines is adequate to demonstrate compliance. NNG shall comply with this limit with monitoring requirements specified in the New Source Performance Standards for Stationary Gas Turbines; previous sulfur monitoring records show that the weight percent of sulfur (H2S) in natural gas at NNG is significantly below the limit. Monitoring based on the New Source Performance Standards for Stationary Combustion Turbines is adequate to demonstrate compliance. NNG shall comply with this limit with monitoring requirements specified in the New Source Performance Standards for Stationary Gas Turbines; previous sulfur monitoring records show that the weight percent of sulfur (H2S) in natural gas at NNG is significantly below the limit. Monitoring based on the New Source Performance Standards for Stationary Spark Ignition Internal Technical Support Document, Permit Number: Page 6 of 8

46 Subject item* IC engine) Requirement (rule basis) Monitoring Discussion CO: 4.0 gr/hp-hr; NOX, CO, and VOC VOC: 1.0 gr/hphr (40 CFR pt. 60, subp. JJJJ) SO2: 0.50 lb/mmbtu; Opacity: 20 % (Minn. R ) None Combustion Engines is adequate to demonstrate compliance. This unit uses natural gas; the likelihood of violating either of the emission limits is very small. Since this is a permit condition, the semi-annual deviations report will document any deviations from the applicable conditions. Design based PTE for SO2, using AP-42, is lb/mmbtu compared to the rule limit of 0.50 lb/mmbtu. EQUI 6 (Heater 1) PM: 0.40 lb/mmbtu; Opacity: 20 % (Minn. R ) None EQUI 7 (Heater 2) *Location of the requirement in the permit (e.g., EQUI 1, STRU 2, etc.). This unit uses natural gas; the likelihood of violating either of the emission limits is very small. Since this is a permit condition, the semi-annual deviations report will document any deviations from the applicable conditions. Design based PTE for PM, using AP-42, is lb/mmbtu compared to the rule limit of 0.50 lb/mmbtu. 3.4 Insignificant activities NNG does not have operations classified as insignificant activities under the MPCA s permitting rules that are required to be listed. 3.5 Permit organization In general, the permit meets the MPCA Tempo Guidance for ordering and grouping of requirements. One area where this permit deviates slightly from Tempo guidance is in the use of appendices. While appendices are fully enforceable parts of the permit, in general, any requirement that the MPCA thinks should be electronically tracked (e.g., limits, submittals, etc.), should be in the Requirements table in Tempo. The main reason is that the appendices are word processing sections and are not part of the electronic tracking system. Violation of the appendices can be enforced, but the computer system will not automatically generate the necessary enforcement notices or documents. Staff must generate these. This permit uses an appendix for specific calculation procedures for limits to avoid Part 70 (COMG 2), 40 CFR pt. 60, subp. KKKK (EQUI 4), and 40 CFR pt. 60, subp. JJJJ (EQUI 5). These procedures are too complex to enter into Tempo and must go in an appendix. 3.6 Comments received Public Notice Period: February 22, 2017 March 23, 2017 EPA Review Period: February 22, 2017 March 23, 2017 Comments were not received during the public notice or EPA review period. 4. Permit fee assessment Attachment 4 to this TSD contains the MPCA s assessment of Application and Additional Points used to determine the permit application fee for this permit action as required by Minn. R The permit action includes only one permit application which was received after the effective date of the rule (July 1, 2009)]. The action includes the incorporation of NESHAP (EQUI 5), NSPS (EQUI 5), and limits to avoid Part 70 (COMG 2) and thus additional fees apply to this permit action. Technical Support Document, Permit Number: Page 7 of 8

47 5. Conclusion Based on the information provided by Northern Natural Gas Co - Faribault Compressor the MPCA has reasonable assurance that the proposed operation of the emission facility, as described in the Air Emission Permit No and this TSD, will not cause or contribute to a violation of applicable federal regulations and Minnesota Rules. Staff members on permit team: Andrea Walkush (permit engineer) Sarah Sevcik (peer reviewer) Beckie Olson (permit writing assistant) Laurie O'Brien (administrative support) Jenna Ness (compliance and enforcement) Curtis Stock (performance testing) TEMPO360 Activities: Major Amendment (IND ), Tracking # 5568 Attachments: 1. PTE summary calculation spreadsheets 2. Requirements development report 3. Subject item inventory/details 4. Points calculator 5. Manufacturer Information and Data to Support PTE Calculations 6. Performance testing report for EQUI 2 7. Sulfur monitoring records Technical Support Document, Permit Number: Page 8 of 8

48 Attachment 1. PTE summary calculation spreadsheets

49 Alternate Format GI-07 Spreadsheet Facility Emissions Summary Air Quality Permit Program Doc Type: Permit Application 1a) AQ Facility ID No.: b) Agency Interest ID No.: 2) Facility Name: Northern Natural Gas Company - Faribault You may use and submit this spreadsheet in place of Form GI-07. Follow the instructions for Form GI-07 to complete this spreadsheet. This spreadsheet can be copied into a tab for your emissions spreadsheet and must be submitted on a CD with your application. If you need to provide emissions information for more emissions units, add more sets of columns (3a through 3f) to the right as needed in the Emissions by Source table. If you need to provide information for more pollutants, add rows as needed. Emissions by Source Table 3a) Delta ID No.: EU 001 3a) Delta ID No.: 3a) Delta ID No.: 3b) Tempo SI ID No.: EQUI 2 3b) Tempo SI ID No.: EQUI 4 3b) Tempo SI ID No.: EQUI 5 3c) 3d) 3e) Potential 3f) 3c) 3d) 3e) Potential 3f) 3c) 3d) 3e) Potential 3f) Pollutant Name CAS # Lbs per Unc Limited Actual Lbs per Unc Limited Actual Lbs per Unc Limited Actual Pollutant Name CAS # Pollutant Name CAS # Hr tpy tpy tpy Hr tpy tpy tpy Hr tpy tpy tpy NOx NOx NOx VOC VOC VOC CO CO CO PM PM PM PM PM PM PM PM PM SO SO SO ,3-Butadiene ,3-Butadiene ,3-Butadiene Acetaldehyde Acetaldehyde Acetaldehyde Acrolein Acrolein Acrolein Benzene Benzene Benzene Biphenyl Biphenyl Biphenyl Carbon Tetrachloride Carbon Tetrachloride Carbon Tetrachloride Chlorobenzene Chlorobenzene Chlorobenzene Chloroform Chloroform Chloroform Ethylbenzene Ethylbenzene Ethylbenzene Ethylene Dibromide Ethylene Dibromide Ethylene Dibromide Formaldehyde Formaldehyde Formaldehyde n-hexane n-hexane n-hexane Methanol Methanol Methanol Methylene Chloride Methylene Chloride Methylene Chloride Naphthalene Naphthalene Naphthalene Phenol Phenol Phenol POM POM POM Propylene Oxide Propylene Oxide Propylene Oxide Styrene Styrene Styrene Toluene Toluene Toluene Vinyl Chloride Vinyl Chloride Vinyl Chloride Xylene Xylene Xylene Total HAP Total HAP Total HAP CO 2 14,908 65,296 65,296 CO 2 15,001 65,702 65,702 CO Methane Methane Methane N 2O N 2O N 2O CO 2e 14,923 65,364 65,364 CO 2e 15,016 65,770 65,770 CO 2e ) Application is being submitted on a compact disc (CD), and the editable calculation spreadsheet(s) are included on the CD. Application is being submitted on paper, and editable calculation spreadsheet(s) are included on an enclosed CD. Page 1 of 3

50 Alternate Format GI-07 Spreadsheet Facility Emissions Summary Air Quality Permit Program Doc Type: Permit Application 1a) AQ Facility ID No.: b) Agency Interest ID No.: 0 1a) AQ Facility ID No.: ) Facility Name: Northern Natural Gas Company - Faribault 2) Facility Name: Northern Natural Gas Company - Faribault Emissions by Source Table 3a) Delta ID No.: FS 001 3a) Delta ID No.: FS 002 3a) Delta ID No.: FS 003 Emissions Summary Table 3b) Tempo SI ID No.: FUGI 3 3b) Tempo SI ID No.: FUGI 2 3b) Tempo SI ID No.: FUGI 1 3c) 3d) 3e) Potential 3f) 3c) 3d) 3e) Potential 3f) 3c) 3d) 3e) Potential 3f) 4a) Potential (lb/hr) 4b) Potential (tons/year) 4c) Actual Pollutant Name CAS # Lbs per Unc Limited Actual Lbs per Unc Limited Actual Lbs per Unc Limited Actual Pollutant Name CAS # Pollutant Name CAS # Hr tpy tpy tpy Hr tpy tpy tpy Hr tpy tpy tpy Pollutant Name Hourly Unrestricted Limited tons/year NOx NOx NOx NOx VOC VOC VOC VOC CO CO CO CO PM PM PM PM PM 10 PM 10 PM 10 PM PM 2.5 PM 2.5 PM 2.5 PM SO2 SO2 SO2 SO ,3-Butadiene Acetaldehyde Acrolein Benzene Biphenyl Carbon Tetrachloride Chlorobenzene Chloroform Ethylbenzene Ethylene Dibromide Formaldehyde n-hexane Methanol Methylene Chloride Naphthalene Phenol POM Propylene Oxide Styrene Toluene Vinyl Chloride Xylene Total HAP CO 2 30, , ,999 Methane N 2O CO 2e 30, , ,362 Page 2 of 3

51 FACILITY-WIDE POTENTIAL EMISSIONS SUMMARY FARIBAULT COMPRESSOR STATION NORTHERN NATURAL GAS COMPANY Emission Criteria Pollutants GHG HAPs Unit NO x VOC CO PM/PM 10/PM 2.5 Lead SO 2 CO 2e Single- HAP Total HAP Limited Limited Limited Limited Limited Limited Limited Limited Limited Emissions Source ID (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) Caterpiller 3406B Emergency Generator EQUI E E E-03 Solar Mars 100-T15000S Turbine EQUI ,923 65,364 65, E E E Solar Mars S Turbine EQUI ,016 65,770 65, E E E-01 Caterpillar G3512 Emergency Generator EQUI E E-01 Heater 1 EQUI Heater 2 EQUI Fugitive VOC Emissions - Valves FUGI Fugitive VOC Emissions - Compressor Seal FUGI Fugitive VOC Emissions - Flanges FUGI Total Facility Emissions , , , Title I Emission Increases , E E-01 Emission Hazardous Air Pollutants Unit 1,3-Butadiene Acetaldehyde Acrolein Arsenic Benzene Beryllium Biphenyl Cadmium Carbon Tetrachloride Limited Limited Limited Limited Limited Limited Limited Limited Limited Emissions Source ID (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) Caterpiller 3406B Emergency Generator EQUI E E E E E E E E E E E E Solar Mars 100-T15000S Turbine EQUI E E E E E E E E E E E E Solar Mars S Turbine EQUI E E E E E E E E E E E E Caterpillar G3512 Emergency Generator EQUI E E E E E E E E E E E E E E E-05 Heater 1 EQUI E E E E E E E E E E E E Heater 2 EQUI E E E E E E E E E E E E Fugitive VOC Emissions - Valves FUGI Fugitive VOC Emissions - Compressor Seal FUGI Fugitive VOC Emissions - Flanges FUGI Total Facility Emissions Emission Hazardous Air Pollutants Unit Chlorobenzene Chloroform Chromium Cobalt Dichlorobenzene Ethylbenzene Ethylene Dibromide Formaldehyde Hexane Limited Limited Limited Limited Limited Limited Limited Limited Limited Emissions Source ID (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) Caterpiller 3406B Emergency Generator EQUI E E E Solar Mars 100-T15000S Turbine EQUI E E E E E E Solar Mars S Turbine EQUI E E E E E E Caterpillar G3512 Emergency Generator EQUI E E E E E E E E E E E E E E E Heater 1 EQUI E E E E E E E E E E E E E E E-03 Heater 2 EQUI E E E E E E E E E E E E E E E-06 Fugitive VOC Emissions - Valves FUGI Fugitive VOC Emissions - Compressor Seal FUGI Fugitive VOC Emissions - Flanges FUGI Total Facility Emissions Emission Hazardous Air Pollutants Unit n-hexane Manganese Mercury Methanol Methylene Chloride Naphthalene Nickel Phenol POM Limited Limited Limited Limited Limited Limited Limited Limited Limited Emissions Source ID (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) Caterpiller 3406B Emergency Generator EQUI E E E-04 Solar Mars 100-T15000S Turbine EQUI E E E E E E-03 Solar Mars S Turbine EQUI E E E E E E-03 Caterpillar G3512 Emergency Generator EQUI E E E E E E E E E E E E E E E E E E-04 Heater 1 EQUI E E E E E E E E E E E E Heater 2 EQUI E E E E E E E E E E E E Fugitive VOC Emissions - Valves FUGI Fugitive VOC Emissions - Compressor Seal FUGI Fugitive VOC Emissions - Flanges FUGI Total Facility Emissions Emission Hazardous Air Pollutants Unit Selenium Propylene Oxide Styrene Toluene Vinyl Chloride Xylene Limited Limited Limited Limited Limited Limited (tpy) Emissions Source ID (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) (tpy) (lb/hr) (tpy) Caterpiller 3406B Emergency Generator EQUI E E E E E E-04 Solar Mars 100-T15000S Turbine EQUI E E E E E E E E E-02 Solar Mars S Turbine EQUI E E E E E E E E E-02 Caterpillar G3512 Emergency Generator EQUI E E E E E E E E E E E E-04 Heater 1 EQUI E E E E E E Heater 2 EQUI E E E E E E Fugitive VOC FUGI Emissions - Valves Fugitive VOC Emissions - Compressor Seal FUGI Fugitive VOC Emissions - Flanges FUGI Total Facility Emissions NNG PTE.xlsx Page 1 of 1 PTE Summary

52 Capacity EQUI 1, STRU 2 POTENTIAL EMISSIONS SUMMARY CATERPILLAR 3406B EMERGENCY GENERATOR FARIBAULT COMPRESSOR STATION NORTHERN NATURAL GAS COMPANY 450 Hp 140,000 Btu/gal 7,000 Btu/hp-hr Emission Factors Potential Emission Rate 3 Emission Factor GHG Emissions Pollutant (lb/hr) 1 (lb/mmbtu) 2 Pollutant (lb/hr) (tpy) (kg/mmbtu) (lb/mmbtu) GWP (lb/hr) (tpy) NO x CO VOC Methane CO N 2 O PM/PM 10 /PM CO 2 e SO ACETALDEHYDE E E E-04 Notes: ACROLEIN E E E Emission factor based on 40 CFR 98, Subpart C, Table C-1. BENZENE E E E Emission factor based on 40 CFR 98, Subpart C, Table C-2. 1,3-BUTADIENE E E E-05 FORMALDEHYDE E E E-04 POM E E E-04 TOLUENE E E E-04 XYLENE E E E-04 SINGLE HAP E E-04 TOTAL HAP E E-03 Notes: 1. Emission factors for NO X, VOC, CO, PM/PM10/PM2.5, and SO2 obtained from manufacturer data. 2. Emissions factors are based on AP-42 factors (AP-42 Section 3.3 Gasoline and Diesel Industrial Engines, Table 3.3-2). 3. Potential emissions based on manufacturer emission factors, maximum horsepower, and 500 hours per year for emergency engines 4. Emission factor shown is for PM. It is conservatively assumed that PM = PM 10 = PM 2.5. NNG PTE.xlsx Page 1 of 10 EQUI 1

53 EQUI 2, STRU 1 POTENTIAL EMISSIONS SUMMARY SOLAR MARS 100-T15000S TURBINE FARIBAULT COMPRESSOR STATION NORTHERN NATURAL GAS COMPANY BTU/scf scfm exhaust Hp MMBtu/hr Above 0 F ,185 16, Below 0 F ,262 16, Pollutant Emission Factors 1,2,3 Potential Emission Rate 4,5 Limited PTE Emission Factor GHG Emissions Limited PTE Pollutant (grams/hp-hr) (lb/mmbtu) (lb/hr) (tpy) (tpy) (kg/mmbtu) (lb/mmbtu) GWP (lb/hr) (tpy) (tpy) NO x c 1 CO ,908 65,296 65,296 VOC Methane CO c N 2 O PM/PM 10 /PM CO 2 e 14,923 65,364 65,364 SO BUTADIENE E E E E-04 Notes: ACETALDEHYDE E E E E Emission factor based on 40 CFR 98, Subpart C, Table C-1. ACROLEIN E E E E Emission factor based on 40 CFR 98, Subpart C, Table C-2. BENZENE E E E E-03 ETHYLBENZENE E E E E-02 FORMALDEHYDE E E E E-01 NAPHTHALENE E E E E-04 POM E E E E-03 PROPYLENE OXIDE E E E E-02 TOLUENE E E E E-02 XYLENE E E E E-02 SINGLE HAP E E E-01 TOTAL HAP E E E-01 Notes: 1. Emission factors for NO X, CO, and VOC obtained from manufacturer data 1a. Emission factors in gr/hp-hr are for emissions when temperatures are less than 0 F, these emission factors are worst case and are used to calculate hourly emissions 1b. Annual average temperatures are above 0 F, therfore annual emissions are calcuated using emissions factors for when temperatures are above 0 F. 1c. To ensure compliance with NO X and CO, a 90 tpy limit is included in this permit (COMG 2) with monthly calculations and recordkeeping using applicable emissions factors based on ambient temperatur 2. Emission factors for SO 2 based on AP-42 (AP-42 Section Stationary Gas Turbines, Table 3.1-2a). Sulfur content is limited to 0.09% by weight 3. Emission factors for HAPs based on AP-42 factors (AP-42 Section Stationary Gas Turbines, Table 3.1-3). 4. Potential emissions based on worst case emission factors, maximum horsepower or maximum MMBtu/hr rating 5. The turbine is equipped with SoLoNOx to minimize emissions, and PACO logic emissions controls minimize emissions when ambient temperatures are less than 0 degrees F. 6. Emission factor for PM based on manufacturer recommendations. PM = PM 10 = PM 2.5 is assumed NNG PTE.xlsx Page 2 of 10 EQUI 2

54 EQUI 4, STRU 3 POTENTIAL EMISSIONS SUMMARY SOLAR MARS 100-T15000S TURBINE FARIBAULT COMPRESSOR STATION NORTHERN NATURAL GAS COMPANY BTU/scf scfm exhaust MMBtu/hr Above 0 F ,218 16, Below 0 F ,276 16, Emission Factors 1,2,3 Potential Emission Rate 4,5 Limited PTE temp < 0 F temp > 0 F Emission Factor GHG Emissions Limited PTE Pollutant Pollutant (grams/hp-hr) (grams/hp-hr) (lb/mmbtu) (lb/hr) (tpy) (tpy) (kg/mmbtu) (lb/mmbtu) GWP (lb/hr) (tpy) (tpy) NO x c 1 CO ,001 65,702 65,702 VOC Methane CO c N 2 O PM/PM 10 /PM CO 2 e 15,016 65,770 65,770 SO BUTADIENE E E E E-04 Notes: ACETALDEHYDE E E E E Emission factor based on 40 CFR 98, Subpart C, Table C-1. ACROLEIN E E E E Emission factor based on 40 CFR 98, Subpart C, Table C-2. BENZENE E E E E-03 ETHYLBENZENE E E E E-02 FORMALDEHYDE E E E E-01 NAPHTHALENE E E E E-04 POM E E E E-03 PROPYLENE OXIDE E E E E-02 TOLUENE E E E E-02 XYLENE E E E E-02 SINGLE HAP E E E-01 TOTAL HAP E E E-01 Notes: 1. Emission factors for NO X, CO, and VOC obtained from manufacturer data 1a. Emission factors when temperatures are less than 0 F are worst case and are used to calculate hourly emissions 1b. Annual average temperatures are above 0 F, therefore annual emissions are calcuated using emissions factors for when temperatures are above 0 F. (Emission factors for NO X, CO, and VOC emissions when tempertures are greater than 0 F are 0.21, 0.21, and 0.12 respectively) 1c. To ensure compliance with NO X and CO, a 90 tpy limit is included in this permit (COMG 2) with monthly calculations and recordkeeping using applicable emissions factors based on ambient temperatures 2. Emission factors for SO 2 based on AP-42 (AP-42 Section Stationary Gas Turbines, Table 3.1-2a). Sulfur content is limited to 0.09% by weight 3. Emission factors for HAPs based on AP-42 factors (AP-42 Section Stationary Gas Turbines, Table 3.1-3). 4. Potential emissions based on worst case emission factors, maximum horsepower or maximum MMBtu/hr rating 5. The turbine is equipped with SoLoNOx to minimize emissions, and PACO logic emissions controls minimize emissions when ambient temperatures are less than 0 degrees F. 6. Emission factor for PM based on manufacturer recommendations. PM = PM10 = PM2.5 is assumed NNG PTE.xlsx Page 4 of 10 EQUI 4

55 Capacity EQUI 5, STRU 4 POTENTIAL EMISSIONS SUMMARY CATERPILLAR G3512 EMERGENCY GENERATOR FARIBAULT COMPRESSOR STATION NORTHERN NATURAL GAS COMPANY 1,102 Hp Btu/scf 905 scfm exhaust 7.8 MMBtu/hr 7059 Btu/hp-hr (per Cat spec sheet) Emission Factors Potential Emission Rate 4 Emission Factor GHG Emissions Pollutant (grams/hp-hr) 1 (lb/mmbtu) 2,3 Pollutant (lb/hr) (tpy) (kg/mmbtu) (lb/mmbtu) GWP (lb/hr) (tpy) NO x CO VOC Methane CO N 2 O PM/PM 10 /PM CO 2 e SO ACETALDEHYDE E E E-02 Notes: ACROLEIN E E E Emission factor based on 40 CFR 98, Subpart C, Table C-1. BENZENE E E E Emission factor based on 40 CFR 98, Subpart C, Table C-2. BIPHENYL E E E-04 CARBON TETRACHLORIDE E E E-05 CHLOROBENZENE E E E-05 CHLOROFORM E E E-05 ETHYLBENZENE E E E-05 ETHYLENE DIBROMIDE E E E-05 FORMALDEHYDE E E-01 N-HEXANE E E E-03 METHANOL E E E-03 METHYLENE CHLORIDE E E E-05 NAPHTHALENE E E E-04 PHENOL E E E-05 POM E E E-04 STYRENE E E E-05 TOLUENE E E E-04 VINYL CHLORIDE E E E-05 XYLENE E E E-04 SINGLE HAP E E-01 TOTAL HAP E E-01 Notes: 1. Emission factors for NO X, CO, VOC, and Formaldehyde obtained from manufacturer data. 2. Emissions factors for SO 2 and PM are based on AP-42 factors (AP-42 Section Stroke Lean-Burn Engines, Table 3.2-2). 3. Potential HAP emissions based on AP-42 factors (AP-42 Section Stroke Lean-Burn Engines, Table 3.2-2). 4. Potential emissions based on manufacturer emission factors, maximum horsepower, and 500 hours per year for emergency engines 5. Emission factor shown is for PM. It is conservatively assumed that PM = PM 10 = PM 2.5. NNG PTE.xlsx Page 5 of 10 EQUI 5

56 POTENTIAL EMISSIONS SUMMARY EQUI 6, STRU 5 FARIBAULT COMPRESSOR STATION NORTHERN NATURAL GAS COMPANY Capacity MMBtu/hr Emission Factors Potential Emission Rates 2 Emission Factor GHG Emissions Pollutant 1 (lb/mmscf) 1 Pollutant (lb/hr) (tpy) (kg/mmbtu) (lb/mmbtu) GWP (lb/hr) (tpy) NO x CO VOC Methane CO N 2 O PM/PM 10 /PM CO 2 e SO LEAD E E-07 Notes: ARSENIC 2.00E E E Emission factor based on 40 CFR 98, Subpart C, Table C-2. BENZENE 2.10E E E Emission factor based on 40 CFR 98, Subpart C, Table C-1. BERYLLIUM 1.20E E E-08 CADMIUM 1.10E E E-06 CHROMIUM 1.40E E E-06 COBALT 8.40E E E-07 DICHLOROBENZENE 1.20E E E-06 FORMALDEHYDE 7.50E E E-04 HEXANE 1.80E E E-03 MANGANESE 3.80E E E-07 MERCURY 2.60E E E-07 NAPTHALENE 6.10E E E-07 NICKEL 2.10E E E-06 POM 1.90E E E-06 SELENIUM 2.40E E E-08 TOLUENE 3.40E E E-06 SINGLE HAP E E-03 TOTAL HAP E E-03 Notes: 1. Emission factors obtained from AP-42 Table through Potential emissions based on maximum firing rate of MMBtu/hr, 1,020 Btu/scf fuel heating value, and 8,760 hours of operation per year. NNG PTE.xlsx Page 6 of 10 EQUI 6

57 POTENTIAL EMISSIONS SUMMARY EQUI 7, STRU 6 FARIBAULT COMPRESSOR STATION NORTHERN NATURAL GAS COMPANY Capacity MMBtu/hr Emission Factors Potential Emission Rates 2 Emission Factor GHG Emissions Pollutant 1 (lb/mmscf) 1 Pollutant (lb/hr) (tpy) (kg/mmbtu) (lb/mmbtu) GWP (lb/hr) (tpy) NO x CO VOC Methane CO N 2 O PM/PM 10 /PM CO 2 e SO LEAD E E-07 Notes: ARSENIC 2.00E E E Emission factor based on 40 CFR 98, Subpart C, Table C-1. BENZENE 2.10E E E Emission factor based on 40 CFR 98, Subpart C, Table C-2. BERYLLIUM 1.20E E E-08 CADMIUM 1.10E E E-06 CHROMIUM 1.40E E E-06 COBALT 8.40E E E-07 DICHLOROBENZENE 1.20E E E-06 FORMALDEHYDE 7.50E E E-04 HEXANE 1.80E E E-03 MANGANESE 3.80E E E-07 MERCURY 2.60E E E-07 NAPTHALENE 6.10E E E-07 NICKEL 2.10E E E-06 POM 1.90E E E-06 SELENIUM 2.40E E E-08 TOLUENE 3.40E E E-06 SINGLE HAP E E-03 TOTAL HAP E E-03 Notes: 1. Emission factors obtained from AP-42 Table through Potential emissions based on maximum firing rate of MMBtu/hr, 1,020 Btu/scf fuel heating value, and 8,760 hours of operation per year. NNG PTE.xlsx Page 7 of 10 EQUI 7

58 POTENTIAL EMISSIONS SUMMARY PROCESS PIPING FUGITIVES FARIBAULT COMPRESSOR STATION NORTHERN NATURAL GAS COMPANY Emission Type of Number of Emission Factors Potential VOC Emission Rates 4 Component Type Unit ID Service 1 Components 1 (lb/hr-component) 2 Percent VOC 3 (lb/hr) (T/yr) Valves FUGI 3 Gas/Vapor % Compressor Seals FUGI 2 Gas/Vapor % Flanges FUGI 1 Gas/Vapor % Totals: Notes: 1. Number of each component and type of service from original permit application for site. 2. Emission factors from MPCA Form EC-14, Table EC Percent VOC from representative gas analysis (refer to Table 7) is 1.05%. To estimate emissions conservatively, the VOC content is assumed to be 5%. 4. Emission rates based on 8,760 of operation hours per year. NNG PTE.xlsx Page 8 of 10 FUGIs

59 EXTENDED GAS ANALYSIS FARIBAULT COMPRESSOR STATION NORTHERN NATURAL GAS COMPANY Molecular Average Component 1 Weight Mol % 2 Molar Weight 3 Mass % 4 Hydrogen Sulfide % % Nitrogen % % Carbon Dioxide % % Methane % % Ethane % % Propane % % i-butane % % n-butane % % i-pentane % % n-pentane % % Hexanes % % Totals: % % 5 VOC Totals: 0.40% % Notes: 1. Typical components listed in gas analysis for field gas. 2. Mol % values obtained from the gas analysis from a representative facility. 3. Molar weight = Molecular weight x Mol % / Average mass % = Molar weight / Total molar weight. 5. VOC Totals include the following components (C3+): Propane i-butane n-butane i-pentane n-pentane Hexanes + NNG PTE.xlsx Page 9 of 10 Gas Analysis

60 COMPRESSOR STATION MINOR SOURCE OPERATING PERMIT APPLICATION Facility Name (all caps): Company Name (all caps): FARIBAULT COMPRESSOR STATION NORTHERN NATURAL GAS COMPANY COMPRESSOR ENGINE INFORMATION: EU-# EU 001 EU 003 EU 004 Normal Normal Less than 0 <0 Mfg./model # - not Mfg./model # (EU-#)- all caps all caps HP hrs/yr HP hrs/yr Non-operating hrs SOLAR MARS 100-T15000S TURBINE SolarMars 100- (EU 001) T15000S Turbine 16,490 6, hrs below ,560 8, hrs below 0 8, hrs below 0 8, hrs below 0 SOLAR MARS S TURBINE SolarMars 100- (EU 003) 16000S Turbine 16,427 5, hrs below ,360 Caterpillar G3512 CATERPILLAR G3512 EMERGENCY Emergency GENERATOR (EU 004) Generator 1, (MMBTU/hr) (MMBTU/hr) - below 0 Normal Below 0 Normal Below EU 001 BTU/scf scfm exhaust EU BTU/scf scfm exhaust EU BTU/scf scfm exhaust Below 0 EU 001 7,467 EU 003 7,608 EU 004 7,059 Btu/hp-hr (per Solar Turbines Inc.) Btu/hp-hr (per Solar Turbines, Inc.) Btu/hp-hr (per Cat spec sheet) -- Emission Factors: Less than 0 Efs verified Emission in lb/hr vary depending on elevation and temperature. Solar provided the lb/hr estimates for NNG (phone conversation Emission Factors with NNG on 12/20/16) EU-# Criteria Pollutant AP-42/Stack Test Normal Less than 0 g/hp-hr lb/hr EQUI 2 Manufacturer Data lb/mmbtu g/hp-hr NOx 0.57 Manufacturer Data Verified Turbine VOC during permit lb/mmbtu g/hp-hr Manufacturer Data action -002 CO and -001 lb/mmbtu g/hp-hr AP-42 lb/mmbtu CO2 PM Manufacturer Recommendation? Manufacturer data for verified AP-42 lb/mmbtu SO2 Formaldehyde AP-42 lb/mmbtu EQUI 3 Turbine EQUI 4 Generator Manufacturer Data NOx g/hp-hr g/hp-hr <0 factors from Beatrice Manufacturer Data VOC g/hp-hr g/hp-hr Manufacturer Data CO g/hp-hr g/hp-hr AP-42 lb/mmbtu CO2 Manufacturer PM Recommendation manufacturer information verified 120 lb lb AP-42 lb/mmbtu lb hr 29 SO2 Formaldehyde AP-42 lb/mmbtu Manufacturer Data NOx g/hp-hr Manufacturer Data VOC g/hp-hr 0.23 Verified in Manufacturer Data Permit CO application g/hp-hr AP-42 lb/mmbtu CO2 PM AP-42 lb/mmbtu 0.01 SO2 AP-42 lb/mmbtu Manufacturer Data Formaldehyde g/hp-hr 0.38 Verified in Permit application NNG PTE.xlsx Page 10 of 10 EFs and Capacity

61 Attachment 2. Requirements development report

62 TSDRequirement(Printversion) SubjectItem ID Seq.# Requirement TFAC1 ( ) 1 PermitAppendices:ThispermitcontainsappendicesaslistedinthepermitTableofContents.ThePermitee shalcomplywithalrequirementscontainedinappendixa.emissioncalculationsforcomg 2,AppendixB. EmissionCalculationsforEQUI4,andAppendixC.EmissionCalculationsforEQUI5. Minn.R ,subp.2 3 PERMITSHIELD:SubjecttothelimitationsinMinn.R ,compliancewiththeconditionsofthispermit shalbedeemedcompliancewiththespecificprovisionoftheapplicablerequirementidentifiedinthepermitas thebasisofeachcondition.subjecttothelimitationsofminn.r and ,subp.2, notwithstandingtheconditionsofthispermitspecifyingcompliancepracticesforapplicablerequirements,any person(includingthepermitee)mayalsouseothercredibleevidencetoestablishcomplianceor noncompliancewithapplicablerequirements. Minn.R ,(A)(2) ThispermitshalnotalterorafecttheliabilityofthePermiteeforanyviolationofapplicablerequirementsprior tooratthetimeofpermitissuance. 7 Circumvention:Donotinstaloruseadeviceormeansthatconcealsordilutesemissions,whichwould otherwiseviolateafederalorstateairpolutioncontrolrule,withoutreducingthetotalamountofpolutant emited. Minn.R AirPolutionControlEquipment:Operatealpolutioncontrolequipmentwheneverthecorespondingprocess equipmentandemissionunitsareoperated. Minn.R ,subp.16(J),Minn. R ,subp.2 9 OperationandMaintenancePlan:Retainatthestationarysourceanoperationandmaintenanceplanforalair polutioncontrolequipment.ataminimum,theo &M planshalidentifyalairpolutioncontrolequipmentand controlpracticesandshalincludeapreventativemaintenanceprogram fortheequipmentandpractices,a Minn.R ,subp.14,Minn.R. descriptionof(theminimum butnotnecessarilytheonly)corectiveactionstobetakentorestoretheequipment ,subp.16(J) andpracticestoproperoperationtomeetapplicablepermitconditions,adescriptionoftheemployeetraining program forproperoperationandmaintenanceofthecontrolequipmentandpractices,andtherecordskeptto demonstrateplanimplementation. 10 OperationChanges:Inanyshutdown,breakdown,ordeviationthePermiteeshalimmediatelytakealpractical stepstomodifyoperationstoreducetheemissionofanyregulatedairpolutant.thecommissionermayrequire feasibleandpracticalmodificationsintheoperationtoreduceemissionsofairpolutants.noemissionsunits Minn.R ,subp.4 thathaveanunreasonableshutdownorbreakdownfrequencyofprocessorcontrolequipmentshalbe permitedtooperate. 11 FugitiveEmissions:Donotcauseorpermitthehandling,use,transporting,orstorageofanymaterialina mannerwhichmayalowavoidableamountsofparticulatematertobecomeairborne.complywithalother requirementslistedinminn.r Minn.R AgencyInterestName:NorthernNaturalGasCo-FaribaultCompressor ActivityNumber:IND

63 SubjectItem ID Seq.# Requirement TFAC1 ( ) 11 requirementslistedinminn.r Noise:ThePermiteeshalcomplywiththenoisestandardssetforthinMinn.R to atal timesduringtheoperationofanyemissionunits.thisisastateonlyrequirementandisnotenforceablebythe EPAAdministratororcitizensundertheCleanAirAct. 13 Inspections:ThePermiteeshalcomplywiththeinspectionproceduresandrequirementsasfoundinMinn.R ,subp.9(A). 14 ThePermiteeshalcomplywiththeGeneralConditionslistedinMinn.R ,subp PerformanceTesting:ConductalperformancetestsinaccordancewithMinn.R.ch.7017unlessotherwise notedinthispermit. 16 PerformanceTestNotificationsandSubmitals: PerformanceTestNotificationandPlan:due30daysbeforeeachPerformanceTest PerformanceTestPre-testMeeting:due7daysbeforeeachPerformanceTest PerformanceTestReport:due45daysaftereachPerformanceTest TheNotification,TestPlan,andTestReportmustbesubmitedinaformatspecifiedbythecommissioner. 17 Limitssetasaresultofaperformancetest(conductedbeforeorafterpermitissuance)applyuntilsuperseded asstatedinthempca'snoticeofcomplianceletergrantingpreliminaryapproval.preliminaryapprovalisbased onformalreviewofasubsequentperformancetestonthesameunitasspecifiedbyminn.r ,subp. 3.Thelimitisfinaluponissuanceofapermitamendmentincorporatingthechange. 18 MonitoringEquipmentCalibration-ThePermiteeshaleither: 1.Calibrateorreplacerequiredmonitoringequipmentevery12months;or 2.Calibrateatthefrequencystatedinthemanufacturer'sspecifications. Foreachmonitor,thePermiteeshalmaintainarecordofalcalibrations,includingthedateconducted,andany corectiveactionthatresulted.thepermiteeshalincludethecalibrationfrequencies,procedures,and manufacturer'sspecifications(ifapplicable)intheoperationsandmaintenanceplan.anyrequirementsapplying tocontinuousemissionmonitorsarelistedseparatelyinthispermit. Minn.R Minn.R ,subp.9(A) Minn.R ,subp.16 Minn.R.ch.7017 Minn.R ,Minn.R ,subps.1-4,Minn.R ,subps.1-2 Minn.R ,subp.3 Minn.R ,subp.4(D) TSDRequirement(Printversion) AgencyInterestName:NorthernNaturalGasCo-FaribaultCompressor ActivityNumber:IND

64 TSDRequirement(Printversion) SubjectItem ID Seq.# 18 Requirement tocontinuousemissionmonitorsarelistedseparatelyinthispermit. TFAC1 ( ) 19 OperationofMonitoringEquipment:Unlessnotedelsewhereinthispermit,monitoringaprocessorcontrol equipmentconnectedtothatprocessisnotnecessaryduringperiodswhentheprocessisshutdown,orduring checksofthemonitoringsystems,suchascalibrationchecksandzeroandspanadjustments.ifmonitoring recordsarerequired,theyshouldreflectanysuchperiodsofprocessshutdownorchecksofthemonitoring system. Minn.R ,subp.4(D) 21 Recordkeeping:Retainalrecordsatthestationarysource,unlessotherwisespecifiedwithinthispermit,fora periodoffive(5)yearsfrom thedateofmonitoring,sample,measurement,orreport.recordswhichmustbe retainedatthislocationincludealcalibrationandmaintenancerecords,aloriginalrecordingsforcontinuous monitoringinstrumentation,andcopiesofalreportsrequiredbythepermit.recordsmustconform tothe requirementslistedinminn.r ,subp.5(a). Minn.R ,subp.5(C) 22 Recordkeeping:Maintainrecordsdescribinganyinsignificantmodifications(asrequiredbyMinn.R , subp.3)orchangescontraveningpermitterms(asrequiredbyminn.r ,subp.2),includingrecords oftheemissionsresultingfrom thosechanges. Minn.R ,subp.5(B) 23 IfthePermiteedeterminesthatnopermitamendmentornotificationisrequiredpriortomakingachange,the PermiteemustretainrecordsofalcalculationsrequiredunderMinn.R Theserecordsshalbekept foraperiodoffiveyearsfrom thedatethatthechangewasmade.therecordsshalbekeptatthestationary Minn.R ,subp.4 sourceforthecurentcalendaryearofoperationandmaybekeptatthestationarysourceoroficeofthe stationarysourceforalotheryears.therecordsmaybemaintainedineitherelectronicorpaperformat. 24 ShutdownNotifications:NotifytheCommissioneratleast24hoursinadvanceofaplannedshutdownofany controlequipmentorprocessequipmentiftheshutdownwouldcauseanyincreaseintheemissionsofany regulatedairpolutant.iftheowneroroperatordoesnothaveadvanceknowledgeoftheshutdown,notification shalbemadetothecommissionerassoonaspossibleaftertheshutdown.however,notificationisnotrequired inthecircumstancesoutlinedinitemsa,bandcofminn.r ,subp.3. Minn.R ,subp.3 Atthetimeofnotification,theowneroroperatorshalinform thecommissionerofthecauseoftheshutdown andtheestimatedduration.theowneroroperatorshalnotifythecommissionerwhentheshutdownisover. 25 BreakdownNotifications:NotifytheCommissionerwithin24hoursofabreakdownofmorethanonehour durationofanycontrolequipmentorprocessequipmentifthebreakdowncausesanyincreaseintheemissions ofanyregulatedairpolutant.the24-hourtimeperiodstartswhenthebreakdownwasdiscoveredorreasonably shouldhavebeendiscoveredbytheowneroroperator.however,notificationisnotrequiredinthe circumstancesoutlinedinitemsa,bandcofminn.r ,subp.2. Minn.R ,subp.2 Atthetimeofnotificationorassoonaspossiblethereafter,theowneroroperatorshalinform thecommissioner ofthecauseofthebreakdownandtheestimatedduration.theowneroroperatorshalnotifythecommissioner whenthebreakdownisover. 26 NotificationofDeviationsEndangeringHumanHealthortheEnvironment:Assoonaspossibleafterdiscovery, notifythecommissionerorthestatedutyoficer,eitheroralyorbyfacsimile,ofanydeviationfrom permit conditionswhichcouldendangerhumanhealthortheenvironment. Minn.R ,subp.1 AgencyInterestName:NorthernNaturalGasCo-FaribaultCompressor ActivityNumber:IND

65 TSDRequirement(Printversion) SubjectItem ID Seq.# 26 Requirement conditionswhichcouldendangerhumanhealthortheenvironment. TFAC1 ( ) 27 NotificationofDeviationsEndangeringHumanHealthortheEnvironmentReport:Within2workingdaysof discovery,notifythecommissionerinwritingofanydeviationfrom permitconditionswhichcouldendanger humanhealthortheenvironment.includethefolowinginformationinthiswritendescription: 1.thecauseofthedeviation; 2.theexactdatesoftheperiodofthedeviation,ifthedeviationhasbeencorected; 3.whetherornotthedeviationhasbeencorected; 4.theanticipatedtimebywhichthedeviationisexpectedtobecorected,ifnotyetcorected;and 5.stepstakenorplannedtoreduce,eliminate,andpreventreoccurenceofthedeviation. Minn.R ,subp.1 28 ThePermiteeshalsubmitasemiannualdeviationsreport:Duesemiannualy,bythe30thofJanuaryandJuly ThefirstsemiannualreportsubmitedbythePermiteeshalcoverthecalendarhalf-yearinwhichthepermitis issued.thefirstreportofeachcalendaryearcoversjanuary1-june30.thesecondreportofeachcalendar yearcoversjuly1-december31.ifnodeviationshaveoccured,thepermiteeshalsubmitthereportstating nodeviations. Minn.R ,subp.6(A)(2) 30 ApplicationforPermitAmendment:Ifapermitamendmentisneeded,submitanapplicationinaccordancewith therequirementsofminn.r throughminn.r submitaldatesvary,dependingonthe typeofamendmentneeded. Uponadoptionofaneworamendedfederalapplicablerequirement,andiftherearemorethan3years remaininginthepermitterm,thepermiteeshalfileanapplicationforanamendmentwithinninemonthsof promulgationoftheapplicablerequirement,pursuanttominn.r ,subp.3. Minn.R ,subp.3,Minn.R ExtensionRequests:ThePermiteemayapplyforanAdministrativeAmendmenttoextendadeadlineina permitbynomorethan120days,providedtheproposeddeadlineextensionmeetstherequirementsofminn.r ,subp.1(H).Performancetestingdeadlinesfrom thegeneralprovisionsof40cfrpt.60andpt.63 Minn.R ,subp.1(H) areexamplesofdeadlinesforwhichthempcadoesnothaveauthoritytograntextensionsandthereforedonot meettherequirementsofminn.r ,subp.1(h). 32 EmissionInventoryReport:dueonorbeforeApril1ofeachcalendaryearfolowingpermitissuance,tobe submitedonaform approvedbythecommissioner. Minn.R EmissionFees:due30daysafterreceiptofanMPCAbil. Minn.R ThePermiteeshalsubmitacompliancescheduleprogressreport:Duesemiannualy,bythe30thofJanuary andjulythecompliancescheduleprogressreportshalcontaintheinformationspecifiedinminn.r ,subp.6(B)andshalbesubmitedonaform approvedbythecommissionerinaccordancewiththe ComplianceSchedulecontainedinthispermit.ProgressReportswilnotbeneededuponcompletionofal activitiescontainedinthecomplianceschedule. Minn.R ,subp.6(B) AgencyInterestName:NorthernNaturalGasCo-FaribaultCompressor ActivityNumber:IND

66 TSDRequirement(Printversion) SubjectItem ID Seq.# 34 Requirement activitiescontainedinthecomplianceschedule. TFAC1 ( ) 35 ThePermiteeshalsubmitacompliancecertification:Dueannualy,bythe31stofJanuary(fortheprevious calendaryear).thepermiteeshalsubmitthistothecommissioneronaform approvedbythecommissioner. Thisreportcoversaldeviationsexperiencedduringthecalendaryear. Minn.R ,subp.6(C) COMG 2 1 ThePermiteeshallimitemissionsofNitrogenOxides<=90tonsperyear12-monthrolingsum tobe calculatedbythe15thdayofeachmonthfortheprevious12-monthperiodasdescribedinthispermit. Toavoidmajorsourceunder40CFR 70.2&Minn.R ThePermiteeshallimitemissionsofCarbonMonoxide<=90tonsperyeartobecalculatedbythe15thdayof eachmonthfortheprevious12-monthperiodasdescribedinthispermit. Toavoidmajorsourceunder40CFR 70.2&Minn.R HourlyRecordkeeping.Whenambienttemperaturesarelessthanorequalto2degreesFahrenheitandgreater thanorequalto0degreesfahrenheit,thepermiteeshalmonitorthetemperatureeveryhourfortemperature changes.thepermiteeshalrecordandmaintaintheambienttemperaturewhileinoperation. Minn.R ,subp DailyRecordkeeping.Onceeachoperatingday,thePermiteeshalcalculate,record,andmaintainthehoursof operationandrecordandmaintaintheambienttemperaturewhileinoperation.thisshalbebasedonwritenor Minn.R ,subps.4-5 electronicusagelogs. 6 MonthlyRecordkeeping.Bythe15thdayofeachmonth,thePermiteeshalcalculateandrecordthefolowing: 1)ThetotalhoursofoperationforEQUI2andEQUI4forthepreviouscalendarmonthusingthedailyrecords whenambienttemperaturesareequaltoorgreaterthan0degreesfahrenheit; 2)ThetotalhoursofoperationforEQUI2andEQUI4forthepreviouscalendarmonthusingthedailyrecords whenambienttemperaturesarelessthan0degreesfahrenheit; 3)TheNOXemissionsforthepreviousmonthusingtheemissionfactors,capacities,andequationsspecifiedin AppendixAofthispermit; 4)TheCO emissionsforthepreviousmonthusingtheemissionfactors,capacities,andequationsspecifiedin AppendixAofthispermit; 5)The12-monthrolingsum NOXemissionsfortheprevious12-monthperiodbysummingthemonthlyNOX emissionsdatafortheprevious12months.. Minn.R ,subps ThePermiteeshalsubmitanannualreport:Dueannualy,bythe31stofJanuaryThereportshaldocument COMG 2NOXandCO 12-monthrolingsum calculationsforthepreviouscalendaryear.thereportshalbe submitedwiththeannualcompliancecertificationrequiredbythispermit.aspartoftheannualreport,the PermiteeshalverifyandcertifythattheFacilityhasmaintainedminorsourcestatusforNewSourceReview. Minn.R ,subp.2 AgencyInterestName:NorthernNaturalGasCo-FaribaultCompressor ActivityNumber:IND

67 TSDRequirement(Printversion) SubjectItem ID Seq.# 7 Requirement PermiteeshalverifyandcertifythattheFacilityhasmaintainedminorsourcestatusforNewSourceReview. EQUI1 (EU002) 1 Opacity<=20percentopacityonceoperatingtemperatureshavebeenatained. Minn.R ,subp.1 2 ThePermiteeshallimitemissionsofSulfurDioxide<=0.50poundspermilionBtuheatinput. Minn.R ,subp.2(A) 3 ThePermiteeshallimitemissionsofSulfurDioxide<=0.0015poundspermilionBtuheatinput.Thislimitis efectiveonjanuary31,2018. Minn.R ,subp.2(B) 4 Fueltype:No.2fueloil/dieselfuelonly. Minn.R ,subp.35a 5 HoursofOperation:ThePermiteeshalmaintaindocumentationonsitethattheunitisanemergencygenerator bydesignthatqualifiesundertheu.s.epamemorandum entitled"calculatingpotentialtoemit(pte)for Minn.R ,subps.4-5 EmergencyGenerators"datedSeptember6,1995,limitingoperationto500hoursperyear. 6 ThePermiteeshalkeeprecordsoffueltypeandusageonamonthlybasis. Minn.R ,subp.5 8 ThePermiteeshal; a.changeoilandfilterevery500hoursofoperationorannualy,whichevercomesfirst; b.inspectaircleanerevery1,000hoursofoperationorannualy,whichevercomesfirst,andreplaceas necessary;and c.inspectalhosesandbeltsevery500hoursofoperationorannualy,whichevercomesfirst,andreplaceas necessary. IfEQUI1isoperatingduringanemergencyanditisnotpossibletoshutdowntheengineinordertoperform the managementpracticerequirementsontheschedulerequiredabove,orifperformingthemanagementpractice ontherequiredschedulewouldotherwiseposeanunacceptableriskunderfederal,state,orlocallaw,the managementpracticecanbedelayeduntiltheemergencyisoverortheunacceptableriskunderfederal,state,. 40CFR (a),40CFRpt.63, subp.zzzz,table2d,minn.r AgencyInterestName:NorthernNaturalGasCo-FaribaultCompressor ActivityNumber:IND

68 SubjectItem ID Seq.# Requirement EQUI1 (EU002) 8 9 IfEQUI1operatesoriscontractualyobligatedtobeavailableformorethan15hourspercalendaryearforthe purposespecifiedin40cfr (f)(4)(i),thepermiteemustusedieselfuelthatmeetstherequirementsin 40CFR80.510(b)fornonroaddieselfuel,exceptthatanyexistingdieselfuelpurchased(orotherwiseobtained) priortojanuary1,2015,maybeuseduntildepleted. 10 ThePermiteemustoperateandmaintainEQUI1accordingtothemanufacturer'semission-relatedwriten instructions. 11 ThePermiteemustinstalanon-resetablehourmeterifoneisnotalreadyinstaled. 12 ThePermiteemustminimizetheengine'stimespentatidleduringstartupandminimizetheengine'sstartup timetoaperiodneededforappropriateandsafeloadingoftheengine,nottoexceed30minutes,afterwhich timetheemissionstandardsapplicabletoaltimesotherthanstartupin40cfrpt.63,subp.zzzz,table2d apply. 13 ThePermiteehastheoptionofutilizinganoilanalysisprogram inordertoextendthespecifiedoilchange requirementin40cfrpt.63,subp.zzzz,table2d.theoilanalysismustbeperformedatthesamefrequency specifiedforchangingtheoilin40cfrpt.63,subp.zzzz,table2d.theanalysisprogram mustataminimum analyzethefolowingthreeparameters:totalbasenumber,viscosity,andpercentwatercontent.the condemninglimitsfortheseparametersareasfolows:totalbasenumberislessthan30percentofthetotal BaseNumberoftheoilwhennew;viscosityoftheoilhaschangedbymorethan20percentfrom theviscosityof theoilwhennew;orpercentwatercontent(byvolume)isgreaterthan0.5.ifalofthesecondemninglimitsare notexceeded,thepermiteeisnotrequiredtochangetheoil.ifanyofthelimitsareexceeded,thepermitee mustchangetheoilwithin2businessdaysofreceivingtheresultsoftheanalysis;iftheengineisnotin operationwhentheresultsoftheanalysisarereceived,thepermiteemustchangetheoilwithin2business daysorbeforecommencingoperation,whicheverislater.thepermiteemustkeeprecordsoftheparameterst. 14 (a)thepermiteemustbeincompliancewiththeemissionlimitations,operatinglimitations,andother requirementsin40cfrpt.63,subp.zzzzthatapplyataltimes. (b)ataltimesthepermiteemustoperateandmaintainanyafectedsource,includingassociatedairpolution controlequipmentandmonitoringequipment,inamannerconsistentwithsafetyandgoodairpolutioncontrol practicesforminimizingemissions.thegeneraldutytominimizeemissionsdoesnotrequirethepermiteeto makeanyfurtherefortstoreduceemissionsiflevelsrequiredbythisstandardhavebeenachieved. Determinationofwhethersuchoperationandmaintenanceproceduresarebeingusedwilbebasedon informationavailabletotheadministratorwhichmayinclude,butisnotlimitedto,monitoringresults,reviewof operationandmaintenanceprocedures,reviewofoperationandmaintenancerecords,andinspectionofthe source. 15 ThePermiteemustdemonstratecontinuouscompliancewitheachemissionlimitation,operatinglimitation,and otherrequirementsin40cfrpt.63,subp.zzzz,table2dthatapplybyoperatingandmaintainingequi1 accordingtothemanufacturer'semission-relatedoperationandmaintenanceinstructions. 40CFR (b),Minn.R CFR (e),Minn.R CFR (f),Minn.R CFR (h),Minn.R CFR (i),Minn.R CFR ,Minn.R CFR (a),40CFRpt.63, subp.zzzz,table6,minn.r TSDRequirement(Printversion) AgencyInterestName:NorthernNaturalGasCo-FaribaultCompressor ActivityNumber:IND

69 SubjectItem ID Seq.# Requirement EQUI1 (EU002) 15 accordingtothemanufacturer'semission-relatedoperationandmaintenanceinstructions. 16 ThePermiteemustreporteachinstanceinwhichtherequirementsin40CFRpt.63,subp.ZZZZ,Table8that applytoequi1werenotmet. 17 ThePermiteemustoperatetheemergencystationaryRICEaccordingtotherequirementsbelow.Inorderfor theenginetobeconsideredanemergencystationaryriceunder40cfrpt.63,subp.zzzz,anyoperation otherthanemergencyoperation,maintenanceandtesting,emergencydemandresponse,andoperationin non-emergencysituationsfor50hoursperyear,asdescribedbelow,isprohibited.ifthepermiteedoesnot operatetheengineaccordingtotherequirementsbelow,theenginewilnotbeconsideredanemergencyengine under40cfrpt.63,subp.zzzzandmustmeetalrequirementsfornon-emergencyengines. (1)ThereisnotimelimitontheuseofemergencystationaryRICEinemergencysituations. (2)ThePermiteemayoperateEQUI1foramaximum of100hourspercalendaryearformaintenancechecks andreadinesstesting,providedthatthetestsarerecommendedbyfederal,stateorlocalgovernment,theman. 18 (a)thepermiteemustkeeprecordsasdescribedbelow; (1)AcopyofeachnotificationandreportthatthePermiteesubmitedtocomplywith40CFRpt.63,subp. ZZZZ,includingaldocumentationsupportinganyInitialNotificationorNotificationofComplianceStatusthatthe Permiteesubmited,accordingtotherequirementin40CFR63.10(b)(2)(xiv). (2)Recordsoftheoccurenceanddurationofeachmalfunctionofoperation(i.e.,processequipment)ortheair polutioncontrolandmonitoringequipment. (3)Recordsofperformancetestsandperformanceevaluationsasrequiredin40CFR63.10(b)(2)(vi).. 19 IfthePermiteeoperatesoriscontractualyobligatedtobeavailableformorethan15hourspercalendaryear forthepurposespecifiedin40cfr (f)(4)(i),thepermiteemustsubmitanannualreportaccordingto therequirementsbelow. (1)Thereportmustcontainthefolowinginformation: (i)companynameandaddresswheretheengineislocated. (i)dateofthereportandbeginningandendingdatesofthereportingperiod. (i)enginesiteratingandmodelyear.. 20 Recordkeeping:ThePermiteeshalmaintainfilesofalinformationrequiredby40CFRpt.63inaform suitable andreadilyavailableforexpeditiousinspectionandreview. Thefilesshouldberetainedforatleast5yearsfolowingthedateofeachoccurence,measurement, maintenance,corectiveaction,report,orrecord.onlythemostrecenttwoyearsofinformationmustbekepton site. 21 ThePermiteeshalmaintain,ataminimum,thefolowinginformationinthefiles: 1)theoccurenceanddurationofeachstartup,shutdown,ormalfunctionofoperationwhenthestartupor shutdowncausesthesourcetoexceedanyapplicableemissionlimitationintherelevantemissionstandards; 2)theoccurenceanddurationofeachmalfunctionofoperation(i.e.,processequipment)ortherequiredair polutioncontrolandmonitoringequipment; 3)almaintenanceperformedontheairpolutioncontrolandmonitoringequipment; 4)actionstakenduringperiodsofstartup,shutdown,andmalfunctionwhensuchactionsarediferentfrom the proceduresspecifiedintheafectedsource'sstartup,shutdown,andmalfunctionplan(ssmp).inthiscase,the Permiteeshalreportthisactionwithin2daysofoccurenceandfolowbyawritennotificationwithin7daysof occurence;. 22 Priortoconstructionorreconstructionofamajor-emiting"afectedsource"underthepromulgatedMACT standards,thepermiteemustapplyforandobtainanairemissionpermit. 40CFR (e),Minn.R CFR (f),Minn.R CFR ,Minn.R CFR (h),Minn.R CFR63.10(b)(1),Minn.R ,subp.2(B) 40CFR63.10(b)(2),Minn.R ,subp.2(B) 40CFR63.5(b)(3)&Minn.R TSDRequirement(Printversion) AgencyInterestName:NorthernNaturalGasCo-FaribaultCompressor ActivityNumber:IND

70 TSDRequirement(Printversion) SubjectItem ID Seq.# 22 Requirement standards,thepermiteemustapplyforandobtainanairemissionpermit. EQUI1 (EU002) 23 AftertheefectivedateofanyrelevantstandardpromulgatedbytheAdministratorunder40CFRpt.63,the Permiteewhoconstructsanewafectedsourcethatisnotmajor-emitingorreconstructsanafectedsource thatisnotmajor-emitingthatissubjecttosuchstandard,orreconstructsasourcesuchthatthesource becomesanafectedsourcesubjecttothestandard,mustnotifytheadministratoroftheintendedconstruction orreconstruction.thenotificationmustbesubmitedinaccordancewiththeproceduresin40cfrsection 63.9(b). 40CFR63.5(b)(4)&Minn.R AftertheefectivedateofanyrelevantstandardpromulgatedbytheAdministratorunder40CFRpt.63, equipmentadded(oraprocesschange)toanafectedsourcethatiswithinthescopeofthedefinitionofafected 40CFR63.5(b),Minn.R sourceundertherelevantstandardmustbeconsideredpartoftheafectedsourceandsubjecttoalprovisions oftherelevantstandardestablishedforthatafectedsource. 25 Circumvention.ThePermiteeshalnotbuild,erect,instal,oruseanyarticle,machine,equipment,orprocessto concealanemissionthatwouldotherwiseconstitutenoncompliancewitharelevantstandard.suchconcealment includes,butisnotlimitedto: 40CFR63.4(b),Minn.R (1)Theuseofdiluentstoachievecompliancewitharelevantstandardbasedontheconcentrationofapolutant intheefluentdischargedtotheatmosphere;or (2)Theuseofgaseousdiluentstoachievecompliancewitharelevantstandardforvisibleemissions. 27 ThePermiteeshalsubmitanotificationofequipmentremoval/dismantlement:Due15calendardaysafter EquipmentRemovaland/orDismantlementDate.ThisnotificationshalspecifywhichSubjectItems(byID#) wereremovedandonwhatdate. Minn.R ,subp.2 EQUI2 (EU001) 1 NitrogenOxides<=0.0157percentbyvolumeat15percentoxygenandonadrybasis. 40CFR60.332(d),Minn.R SulfurDioxide<=0.015percentbyvolumeat15percentoxygenandonadrybasis. 40CFR60.333(a),Minn.R SulfurDioxide<=0.50poundspermilionBtuheatinput(Thepotentialtoemitfrom theunitis0.0846lb/mmbtu duetoequipmentdesignandalowablefuels.). Minn.R ,subp.2(A) AgencyInterestName:NorthernNaturalGasCo-FaribaultCompressor ActivityNumber:IND

71 TSDRequirement(Printversion) SubjectItem ID Seq.# 3 Requirement duetoequipmentdesignandalowablefuels.). EQUI2 (EU001) 4 SulfurDioxide<=0.0015poundspermilionBtuheatinputThislimitisefectiveonJanuary1,2018. Minn.R ,subp.2(B) 5 Opacity<=20percentopacityonceoperatingtemperatureshavebeenatained. Minn.R ,subp.1 6 SulfurContentofFuel<=0.09percentbyweight.Thislimitismorestringentthan40CFR60.333(b).The Minn.R ,subp.2,Toavoid Permiteeshalcomplywiththislimitbycomplyingwiththesulfurmonitoringrequirementsunder40CFRpt.60, majorsourceunder40cfr70.2& subp.gg. Minn.R SulfurContentofFuel<=0.8percentbyweight. 40CFR60.333(b),Minn.R Fueltype:Naturalgasonly. Minn.R ,subp.35a 9 Reporting:Ifthereisachangeinfuelsupply,thePermiteemustnotifytheMPCAofsuchchangefor re-examinationofthecustom fuel-monitoringschedule.asubstantialchangeinfuelqualityshalbeconsidered asachangeinfuelsupply.sulfurmonitoringshalbeconductedweeklyduringtheinterim periodwhenthis custom scheduleisbeingre-examined. 40CFR60.334(b),Minn.R ThePermiteeshalkeeprecordsoffueltypeandusageonamonthlybasis. Minn.R ,subp.5 AgencyInterestName:NorthernNaturalGasCo-FaribaultCompressor ActivityNumber:IND

72 TSDRequirement(Printversion) SubjectItem ID Seq.# 10 Requirement ThePermiteeshalkeeprecordsoffueltypeandusageonamonthlybasis. EQUI2 (EU001) 11 AnalysisforfuelsulfurcontentofthenaturalgasshalbeconductedusingoneoftheapprovedASTM reference methodsforthemeasurementofsulfuringaseousfuels,oranapprovedalternativemethod. 40CFR60.334(b),Minn.R Sulfurmonitoringshalbeconductedtwicemonthlyforsixmonths.Ifthismonitoringshowslitlevariabilityinthe fuelsulfurcontent,andindicatesconsistentcompliancewith40cfrsection60.333,thensulfurmonitoringshal 40CFR60.334(b),Minn.R beconductedonceperquarterforsixquarters. 13 SulfurMonitoring:If,afterthefirst2yearsofsulfurmonitoring,thesulfurcontentofthefuelshowslitle variabilityand,whencalculatedassulfurdioxide,representsconsistentcompliancewiththesulfurdioxide emissionlimitsspecifiedunder40cfrsection60.333,sampleanalysisshalbeconductedtwiceperannum. Thismonitoringshalbeconductedduringthefirstandthirdquartersofeachcalendaryear. 40CFR60.334(b),Minn.R Notificationofnoncompliance:Shouldanysulfuranalysisindicatenoncompliancewith40CFRSection60.333, thepermiteeshalnotifythempcaofsuchexcessemissionsandthecustom fuelmonitoringscheduleshalbe 40CFR60.334(b),Minn.R re-examinedbytheadministrator.sulfurmonitoringshalbeconductedweeklyduringtheinterim periodwhen thiscustom fuel-monitoringscheduleisbeingre-examined. 15 Recordkeeping:Recordsofsampleanalysesandfuelsupplypertinenttothecustom fuel-monitoringschedule shalberetainedforaperiodoffiveyears,andbeavailableforinspectionbypersonneloffederal,state,and localairpolutioncontrolagencies. 40CFR60.334(b),Minn.R ThePermiteeshalsubmitanotificationofanyphysicaloroperationalchangewhichincreasesemissionrate: due60days(orassoonaspractical)beforethechangeiscommenced. 40CFR60.7(a)(4),Minn.R ,subp.1 17 Recordkeeping:ThePermiteeshalmaintainrecordsoftheoccurenceanddurationofanystartup,shutdown, 40CFR60.7(b),Minn.R , ormalfunctionintheoperationofthefacilityincluding;anymalfunctionoftheairpolutioncontrolequipment;or subp.1 anyperiodsduringwhichacontinuousmonitoringsystem ormonitoringdeviceisinoperative. AgencyInterestName:NorthernNaturalGasCo-FaribaultCompressor ActivityNumber:IND

73 TSDRequirement(Printversion) SubjectItem ID Seq.# 17 Requirement anyperiodsduringwhichacontinuousmonitoringsystem ormonitoringdeviceisinoperative. EQUI2 (EU001) 18 40CFR60.7(f),Minn.R , Recordkeeping:ThePermiteeshalmaintainafileofalmeasurements,maintenance,reportsandrecordsforat subp.5(c),minn.r ,subp. leastfiveyears.thisrequirementismorestringentthan40cfrsection60.7(f),whichspecifiestwoyears Noowneroroperatorshalbuild,erect,instal,oruseanyarticle,machine,equipmentorprocess,theuseof whichconcealsanemissionwhichwouldotherwiseconstituteaviolationofanapplicablestandard. 40CFR60.12,Minn.R NitrogenOxides:ThePermiteeshalconductaperformancetest:DueafterPermitIssuanceDateevery60 monthstomeasureemissions.thefirsttestisduebythedatespecifiedandalsubsequenttestsareduebythe endofeach60-monthperiodfolowingthatdate.theperformancetestshalbeconductedatworstcase conditionsasdefinedatminn.r ,subp.2,usingepareferencemethod7e,orothermethod approvedbympcaintheperformancetestplanapproval. Minn.R ,subp.1 Testingconductedduringthe60dayspriortotheperformancetestduedatesatisfiestheperformancetestdue date,andwilnotresetthetestduedateforfuturetestingasrequired: 1)bythispermit; 2)bythemostrecentlyapprovedPerformanceTestFrequencyPlan;or 3)withinaNoticeofComplianceleter.Testingconductedmorethantwomonthspriortotheperformancetest. 21 SulfurContentofFuel:ThePermiteeshalsubmitanannualreport:Dueannualy,bythe31stofJanuary.The reportshaldocumentthesulfurmonitoringanalysisresultsforthepreviouscalendaryear.thereportshalbe submitedwiththeannualcompliancecertificationrequiredbythispermit. Minn.R ,subp.2 EQUI4 1 ThePermiteeshallimitemissionsofNitrogenOxides<=25partspermilionat15percentoxygen,or150ng/J ofusefuloutput(1.2lb/mwh). 40CFR (a),40CFRpt.60, Table1,Minn.R ThePermiteeshallimitemissionsofSulfurDioxide<=110nanogramsperjoule(0.90lb/MWh)grossoutput. 40CFR (a)(1),Minn.R Opacity<=20percentopacityonceoperatingtemperatureshavebeenatained. Minn.R ,subp.1 AgencyInterestName:NorthernNaturalGasCo-FaribaultCompressor ActivityNumber:IND

74 TSDRequirement(Printversion) SubjectItem ID Seq.# 3 Requirement Opacity<=20percentopacityonceoperatingtemperatureshavebeenatained. EQUI4 4 SulfurDioxide<=0.50poundspermilionBtuheatinput(Thepotentialtoemitfrom theunitis0.0846lb/mmbtu duetoequipmentdesignandalowablefuels). Minn.R ,subp.2(A) 5 SulfurDioxide<=0.0015poundspermilionBtuheatinputThislimitisefectiveonJanuary31,2018. Minn.R ,subp.2(B) 6 SulfurContentofFuel<=0.09percentbyweight.ThePermiteeshalcomplywiththislimitbycomplyingwith thesulfurmonitoringrequirementsunder40cfrpt.60,subp.kkkk. Minn.R ,subp.2,Toavoid majorsourceunder40cfr70.2& Minn.R ThePermiteeisauthorizedtoconstructandoperateEQUI4meetingthefolowingdesignrequirements,within 18monthsafterpermitissuanceofPermitNo Theunitshalmeetalapplicablerequirementsof thispermit. Minn.R ,subp.2 DesignRequirements; 16,696horsepower/hourcapacity. 9 Fueltype:Naturalgasonly. Minn.R ,subp.35a 10 ThePermiteeshalkeeprecordsoffueltypeandusageonamonthlybasis. Minn.R ,subp.5 11 ThePermiteeshaloperateandmaintainEQUI4stationarycombustionturbine,airpolutioncontrolequipment, andmonitoringequipmentinamannerconsistentwithgoodairpolutioncontrolpracticesforminimizing 40CFR ,Minn.R emissionsataltimesincludingduringstartup,shutdown,andmalfunction. AgencyInterestName:NorthernNaturalGasCo-FaribaultCompressor ActivityNumber:IND

75 TSDRequirement(Printversion) SubjectItem ID Seq.# 11 Requirement emissionsataltimesincludingduringstartup,shutdown,andmalfunction. EQUI4 ThePermiteemustconductaninitialperformancetest,asrequiredin40CFR60.8forNOX.SubsequentNOX performancetestsshalbeconductedonanannualbasis(nomorethan14calendarmonthsfolowingthe previousperformancetest). 12 ForeachNOXperformancetestrun,thePermiteeshalmeasuretheNOXanddiluentgasconcentrations, 40CFR (a)(1)(i),Minn.R. usingeitherepamethods7eand3a,orepamethod20inappendixaof40cfrpt.60toconduct performancetests.concurentlymeasuretheheatinputtotheunit,usingafuelflowmeter(orflowmeters),and measuretheelectricalandthermaloutputoftheunit.useepamethod19inappendixaof40cfrpt.60to calculatethenoxemissionrateinlb/mmbtu.then,useequations1and,ifnecessary,2and3in40cfr (f)tocalculatetheNOXemissionrateinlb/MWh.40CFR (f)equationsarelistedinAppendixB ofthispermit. CalculatethehourlyaverageNOXemissionrates,inunitsoftheemissionstandardsunder40CFR , usingeitherppm forunitscomplyingwiththeconcentrationlimitorequation1of40cfr (f)forunits complyingwiththeoutputbasedstandard. 14 Forcombined-cycleandcombinedheatandpowercomplyingwiththeoutput-basedstandard,useEquation1of 40CFR (f),Minn.R CFR (f),exceptthatthegrossenergyoutputiscalculatedasthesum ofthetotalelectricaland mechanicalenergygeneratedbythecombustionturbine,theadditionalelectricalormechanicalenergy(ifany) generatedbythesteam turbinefolowingtheheatrecoverysteam generator,and100percentofthetotaluseful thermalenergyoutputthatisnotusedtogenerateadditionalelectricityormechanicaloutput,expressedin equivalentmw,asintheequations2and3of40cfr (f). 15 SamplingtraversepointsforNOXaretobeselectedfolowingEPAMethod20andsampledforequaltime intervals.thesamplingmustbeperformedwithatraversingsingle-holeprobe,or,iffeasible,withastationary multi-holeprobethatsampleseachofthepointssequentialy.alternatively,amulti-holeprobedesignedand documentedtosampleequalvolumesfrom eachholemaybeusedtosamplesimultaneouslyattherequired points. 40CFR (a)(2),Minn.R ThePermiteemustdemonstratecompliancewiththeNOXemissionlimitin40CFR ateachtestedload 40CFR (b)(4),Minn.R. level.complianceisachievedifthethree-runarithmeticaveragenoxemissionrateateachtestedlevelmeets theapplicableemissionlimitin40cfr TheNOXperformancetestmustbedoneatanyloadconditionwithinplusorminus25percentof100percentof peakload.thepermiteemayperform testingatthehighestachievableloadpoint,ifatleast75percentofpeak 40CFR (b),Minn.R. loadcannotbeachievedinpractice.thepermiteemustconductthreeseparatetestrunsforeachperformance test.theminimum timeperrunis20minutes. 18 Theambienttemperaturemustbegreaterthan0 FduringtheNOXperformancetest. 40CFR (b)(6),Minn.R (a)thepermiteemustconductaninitialperformancetest,asrequiredin40cfr60.8forso2.subsequent SO2performancetestsshalbeconductedonanannualbasis(nomorethan14calendarmonthsfolowingthe previousperformancetest). 19 (1)ThePermiteeshalperiodicalydeterminethesulfurcontentofthefuelcombustedintheturbine,thereforea representativefuelsampleshalbecolectedfolowingastm D5287(incorporatedbyreference,see40CFR 40CFR ,Minn.R )fornaturalgastoconductSO2performancetests.Thefuelanalysesof40CFR maybe performedeitherbythepermitee,aservicecontractorretainedbythepermitee,thefuelvendor,oranyother qualifiedagency.analyzethesamplesforthetotalsulfurcontentofthefuelusing: (i)forgaseousfuels,astm D1072,oralternativelyD3246,D4084,D4468,D4810,D6228,D6667,orGasPro. AgencyInterestName:NorthernNaturalGasCo-FaribaultCompressor ActivityNumber:IND

76 SubjectItem ID Seq.# Requirement EQUI ThePermiteeshalmonitorthetotalsulfurcontentofthefuelbeingfiredintheturbine.Thesulfurcontentofthe fuelmustbedeterminedusingtotalsulfurmethodsdescribedin40cfr alternatively,ifthetotalsulfur contentofthegaseousfuelduringthemostrecentperformancetestwaslessthanhalftheapplicablelimit, ASTM D4084,D4810,D5504,orD6228,orGasProcessorsAssociationStandard2377(alofwhichare incorporatedbyreference,see40cfr60.17),whichmeasurethemajorsulfurcompounds,maybeused. 21 (i)thepermiteeshalmaintaindailytotalsulfurcontentmeasurementsfor30consecutiveunitoperatingdays, usingtheapplicablemethodsspecifiedin40cfrpt.60subp.kkkk.basedontheresultsofthe30daily samples,therequiredfrequencyforsubsequentmonitoringofthefuel'stotalsulfurcontentshalbeasspecified in40cfr (c)(1)(i),(i),or(iv),asapplicable. (i)ifnoneofthe30dailymeasurementsofthefuel'stotalsulfurcontentexceedshalftheapplicablestandard, subsequentsulfurcontentmonitoringmaybeperformedat12-monthintervals.ifanyofthesamplestakenat 12-monthintervalshasatotalsulfurcontentgreaterthanhalfbutlessthantheapplicablelimit,folowthe proceduresin40cfr (c)(1)(i).ifanymeasurementexceedstheapplicablelimit,folowtheprocedures in40cfr (c)(1)(iv).. 22 ThePermiteeshalsubmitreportsofexcessemissionsandmonitordowntime,inaccordancewith40CFR 60.7(c)forEQUI4thatrequiresthePermiteetoperiodicalydeterminethefuelsulfurcontent.Excessemissions mustbereportedforalperiodsofunitoperation,includingstart-up,shutdown,andmalfunction. 23 ThePermiteeshalsubmitawritenreportoftheresultsofeachperformancetestbeforethecloseofbusiness onthe60thdayfolowingthecompletionoftheperformancetest. 24 Excessemissionsandmonitoringdowntimeformonitoringthesulfurcontentoffuelaredefinedasfolows: (a)forsamplesofgaseousfuelandforoilsamplesobtainedusingdailysampling,flowproportionalsampling,or samplingfrom theunit'sstoragetank,anexcessemissionoccurseachunitoperatinghourincludedintheperiod beginningonthedateandhourofanysampleforwhichthesulfurcontentofthefuelbeingfiredinthe combustionturbineexceedstheapplicablelimitandendingonthedateandhourthatasubsequentsampleis takenthatdemonstratescompliancewiththesulfurlimit. (c)aperiodofmonitordowntimebeginswhenarequiredsampleisnottakenbyitsduedate.aperiodof monitordowntimealsobeginsonthedateandhourofarequiredsample,ifinvalidresultsareobtained.the periodofmonitordowntimeendsonthedateandhourofthenextvalidsample. 25 ThePermiteeshalsubmitanotificationofanyphysicaloroperationalchangewhichincreasesemissionrate: due60days(orassoonaspractical)beforethechangeiscommenced. 26 Recordkeeping:ThePermiteeshalmaintainrecordsoftheoccurenceanddurationofanystartup,shutdown, ormalfunctionintheoperationofthefacilityincluding;anymalfunctionoftheairpolutioncontrolequipment;or anyperiodsduringwhichacontinuousmonitoringsystem ormonitoringdeviceisinoperative. 40CFR ,Minn.R CFR (c)(1),Minn.R CFR (a),Minn.R CFR (b),Minn.R CFR ,Minn.R CFR60.7(a)(4),Minn.R ,subp.1 40CFR60.7(b),Minn.R , subp.1 TSDRequirement(Printversion) AgencyInterestName:NorthernNaturalGasCo-FaribaultCompressor ActivityNumber:IND

77 TSDRequirement(Printversion) SubjectItem ID Seq.# 26 Requirement anyperiodsduringwhichacontinuousmonitoringsystem ormonitoringdeviceisinoperative. EQUI CFR60.7(f),Minn.R , Recordkeeping:ThePermiteeshalmaintainafileofalmeasurements,maintenance,reportsandrecordsforat subp.5(c),minn.r ,subp. leastfiveyears.thisrequirementismorestringentthan40cfrsection60.7(f),whichspecifiestwoyears Noowneroroperatorshalbuild,erect,instal,oruseanyarticle,machine,equipmentorprocess,theuseof whichconcealsanemissionwhichwouldotherwiseconstituteaviolationofanapplicablestandard. 40CFR60.12,Minn.R NitrogenOxides:Asrequiredin40CFR60.8,thePermiteeshalconductaninitialperformancetestwithin60 daysafterachievingthemaximum productionrateatwhichthefacilitywilbeoperated,butnolaterthe Permiteeshalconductaninitialperformancetest:Due180calendardaysafterInitialStartupDate.The performancetestshalbeconductedatworstcaseconditionsasdefinedatminn.r ,subp.2,using EPAReferenceMethod20,orothermethodapprovedbyMPCAintheperformancetestplanapproval. 40CFR (a),Minn.R NitrogenOxides:ThePermiteeshalconductaperformancetest:Dueannualy,butnomorethan14months folowingthepreviousperformancetest.theperformancetestshalbeconductedatworstcaseconditionsas definedatminn.r ,subp.2,usingepareferencemethod20,orothermethodapprovedbympca intheperformancetestplanapproval. ThePermiteeisnotusingwaterorsteam injectiontocontrolnoxemissions. IftheNOXemissionresultfrom theperformancetestislessthanorequalto75percentofthenoxemission limitfortheturbine,thepermiteemayreducethefrequencyofsubsequentperformanceteststoonceevery2 years(nomorethan26calendarmonthsfolowingthepreviousperformancetest).iftheresultsofany subsequentperformancetestexceed75percentofthenoxemissionlimitfortheturbine,thepermiteemustr. 40CFR ,40CFR (a), Minn.R SulfurDioxide:Asrequiredin40CFR60.8,thePermiteeshalconductaninitialperformancetestwithin60 daysafterachievingthemaximum productionrateatwhichthefacilitywilbeoperated,butnolaterthe Permiteeshalconductaninitialperformancetest:Due180calendardaysafterInitialStartupDateThe performancetestshalbeconductedatworstcaseconditionsasdefinedatminn.r ,subp.2,using EPAReferenceMethod20,orothermethodapprovedbyMPCAintheperformancetestplanapproval. 40CFR (a),Minn.R SulfurDioxide:ThePermiteeshalconductaperformancetest:Dueannualy,butnomorethan14months folowingthepreviousperformancetest.theperformancetestshalbeconductedatworstcaseconditionsas definedatminn.r ,subp.2,usingepareferencemethod20,orothermethodapprovedbympca intheperformancetestplanapproval. 40CFR (a),Minn.R ThePermiteeshalsubmitanotificationofdateconstructionbegan:Due30calendardaysafterDateof ConstructionStart.SubmitthenameandnumberoftheSubjectItem andthedateconstructionbegan. 40CFR60.7(a)(1),Minn.R ,subp.16(L),Minn.R ,subp.1 AgencyInterestName:NorthernNaturalGasCo-FaribaultCompressor ActivityNumber:IND

78 TSDRequirement(Printversion) SubjectItem ID Seq.# 33 Requirement ConstructionStart.SubmitthenameandnumberoftheSubjectItem andthedateconstructionbegan. EQUI4 34 ThePermiteeshalsubmitanotificationoftheactualdateofinitialstartup:Due15calendardaysafterInitial StartupDate.SubmitthenameandnumberoftheSubjectItem andthedateofstartup.startupisasdefinedin Minn.R ,subp.42a. 40CFR60.7(a)(3),Minn.R ,subp.16(L),Minn.R ,subp.1 35 SulfurContentofFuel:ThePermiteeshalsubmitanannualreport:Dueannualy,bythe31stofJanuary.The reportshaldocumentthesulfurmonitoringanalysisresultsforthepreviouscalendaryear.thereportshalbe submitedwiththeannualcompliancecertificationrequiredbythispermit. Minn.R ,subp.2 EQUI5 1 ThePermiteeshallimitemissionsofNitrogenOxides<=2.0gramsperhorsepower-hour. 40CFR (e),40CFR (c),40CFRpt.60,subp.JJJJ, Table1,Minn.R ,Minn.R ThePermiteeshallimitemissionsofCarbonMonoxide<=4.0gramsperhorsepower-hour. 40CFR (e),40CFR (c),40CFRpt.60,subp.JJJJ, Table1,Minn.R ,Minn.R ThePermiteeshallimitemissionsofVolatileOrganicCompounds<=1.0gramsperhorsepower-hour. 40CFR (e),40CFR (c),40CFRpt.60,subp.JJJJ, Table1,Minn.R ,Minn.R Opacity<=20percentopacityonceoperatingtemperatureshavebeenatained. Minn.R ,subp.1 5 SulfurDioxide<=0.50poundspermilionBtuheatinput.Thepotentialtoemitfrom theunitis lb/mmbtuduetoequipmentdesignandalowablefuels. Minn.R ,subp.2(A) AgencyInterestName:NorthernNaturalGasCo-FaribaultCompressor ActivityNumber:IND

79 TSDRequirement(Printversion) SubjectItem ID Seq.# 5 Requirement lb/mmbtuduetoequipmentdesignandalowablefuels. EQUI5 6 SulfurDioxide<=0.0015poundspermilionBtuheatinput.ThislimitisefectiveonJanuary31,2018.The potentialtoemitfrom theunitis lb/mmbtuduetoequipmentdesignandalowablefuels. Minn.R ,subp.2(B) 7 ThePermiteeisauthorizedtoconstructandoperateEQUI5meetingthefolowingdesignrequirements,within 18monthsafterpermitissuanceofPermitNo Theunitshalmeetalapplicablerequirementsof thispermit. Minn.R ,subp.2 DesignRequirements: 1,102brakehorsepower/hour SI-4SLBfiringmethod. 8 Fueltype:Naturalgasonly. Minn.R ,subp.35a 9 HoursofOperation:ThePermiteeshalmaintaindocumentationonsitethattheunitisanemergencygenerator bydesignthatqualifiesundertheu.s.epamemorandum entitled"calculatingpotentialtoemit(pte)for Minn.R ,subps.4-5 EmergencyGenerators"datedSeptember6,1995,limitingoperationto500hoursperyear. 10 ThePermiteeshalkeeprecordsoffueltypeandusageonamonthlybasis. Minn.R ,subp.5 12 EQUI5isanewstationaryRICElocatedatanareasourceandthePermiteemustmeettherequirementsof40 CFRpt.63,subp.ZZZZbymeetingtherequirementsof40CFRpt.60subp. I,forcompressionignition 40CFR (c)(1),Minn.R. enginesor40cfrpt.60subp.jjjj,forsparkignitionengines.nofurtherrequirementsapplyforsuchengines under40cfrpt.63,subp.zzzz. 13 ThePermiteeisanownerandoperatorofEQUI5thatisanemergencystationarySIICEwithamaximum enginepowergreaterthan19kw (25HP)thatcommencedconstructionafterJune12,2006,andwas manufacturedonorafterjanuary1, CFR (a)(4),40CFR (c),Minn.R ,Minn. R AgencyInterestName:NorthernNaturalGasCo-FaribaultCompressor ActivityNumber:IND

80 SubjectItem ID Seq.# Requirement EQUI5 13 manufacturedonorafterjanuary1, ThePermiteeshalnotinstalenginesthatdonotmeettheapplicablerequirementsin40CFR after January1, ThePermiteemustinstalanon-resetablehourmeter. 17 ThePermiteemustoperateandmaintainEQUI5thatachievestheemissionstandardsasrequiredin40CFR overtheentirelifeoftheengine. 18 ThePermiteemustoperateEQUI5accordingtotherequirementsin40CFR (d)(1)through(3).In orderfortheenginetobeconsideredanemergencystationaryiceunder40cfrpt.60,subp.jjjj,any operationotherthanemergencyoperation,maintenanceandtesting,emergencydemandresponse,and operationinnon-emergencysituationsfor50hoursperyear,asdescribedin40cfr (d)(1)through (3),isprohibited.IfthePermiteedoesnotoperatetheengineaccordingtotherequirementsin40CFR (d)(1)through(3),theenginewilnotbeconsideredanemergencyengineunder40CFRpt.60,subp. JJJJandmustmeetalrequirementsfornon-emergencyengines. (1)ThereisnotimelimitontheuseofemergencystationaryICEinemergencysituations. (2)ThePermiteemayoperateEQUI5foranycombinationofthepurposesspecifiedin40CFR (d)(2. 19 ThePermiteeispurchasinganon-certifiedenginethatmustdemonstratecompliancewiththeemission standardsspecifiedin40cfr (d),accordingtotherequirementsspecifiedin40cfr ,as applicable,andaccordingto40cfr (b)(2)(i). ThePermiteemustkeepamaintenanceplanandrecordsofconductedmaintenanceandmust,totheextent practicable,maintainandoperatetheengineinamannerconsistentwithgoodairpolutioncontrolpracticefor minimizingemissions.inaddition,thepermiteemustconductaninitialperformancetestandconduct subsequentperformancetestingevery8,760hoursor3years,whichevercomesfirst,thereaftertodemonstrate compliance. 20 (a)eachperformancetestmustbeconductedwithin10percentof100percentpeak(orthehighestachievable) loadandaccordingtotherequirementsin40cfr60.8andunderthespecificconditionsthatarespecifiedby 40CFRpt.60,subp.JJJJ,Table2. (b)thepermiteeshalnotconductperformancetestsduringperiodsofstartup,shutdown,ormalfunction,as specifiedin40cfr60.8(c).ifequi5isnon-operational,thepermiteedoesnotneedtostartuptheengine solelytoconductaperformancetest;however,thepermiteemustconducttheperformancetestimmediately uponstartupoftheengine. (c)thepermiteemustconductthreeseparatetestrunsforeachperformancetestrequiredin40cfr , asspecifiedin40cfr60.8(f).eachtestrunmustbeconductedwithin10percentof100percentpeak(orthe. 21 ThePermiteemustsubmitacopyofeachperformancetestasconductedin40CFR within60days afterthetesthasbeencompleted.performancetestreportsusingepamethod18,epamethod320,orastm D (incorporatedbyreference see40cfr60.17)tomeasurevocrequirereportingofalqa/qcdata. ForMethod18,reportresultsfrom sections8.4and ;formethod320,reportresultsfrom sections8.6.2, 9.0,and13.0;andforASTM D reportresultsofalQA/QCproceduresinAnnexes CFR (c),40CFR (c),Minn.R ,Minn. R CFR (a),40CFR (c),Minn.R ,Minn. R CFR ,40CFR (c), Minn.R ,Minn.R CFR (d),40CFR (c),Minn.R ,Minn. R CFR (b)(2)(i),40CFR (c),Minn.R ,Minn. R CFR ,40CFR (c), Minn.R ,Minn.R CFR (d),40CFR (c),Minn.R ,Minn. R TSDRequirement(Printversion) AgencyInterestName:NorthernNaturalGasCo-FaribaultCompressor ActivityNumber:IND

81 TSDRequirement(Printversion) SubjectItem ID Seq.# 21 Requirement 9.0,and13.0;andforASTM D reportresultsofalQA/QCproceduresinAnnexes1-7. EQUI5 ThePermiteemustkeepthefolowingrecordsoftheinformation: 22 (1)Alnotificationssubmitedtocomplywith40CFRpt.60,subp.JJJJandaldocumentationsupportingany notification. (2)Maintenanceconductedontheengine. (4)Documentationthattheenginemeetstheemissionstandards. 40CFR (a),40CFR (c),Minn.R ,Minn. R ThePermiteemustsubmitaninitialnotificationasrequiredin40CFR60.7(a)(1).Thenotificationmustinclude theinformationbelow: (1)NameandaddressofthePermitee; (2)Theaddressoftheafectedsource; (3)Engineinformationincludingmake,model,enginefamily,serialnumber,modelyear,maximum engine power,andenginedisplacement; (4)Emissioncontrolequipment;and. 40CFR (c),40CFR (c),Minn.R ,Minn. R ThePermiteeshalsubmitanotificationofanyphysicaloroperationalchangewhichincreasesemissionrate: due60days(orassoonaspractical)beforethechangeiscommenced. 40CFR60.7(a)(4),Minn.R ,subp.1 25 Recordkeeping:ThePermiteeshalmaintainrecordsoftheoccurenceanddurationofanystartup,shutdown, 40CFR60.7(b),Minn.R , ormalfunctionintheoperationofthefacilityincluding;anymalfunctionoftheairpolutioncontrolequipment;or subp.1 anyperiodsduringwhichacontinuousmonitoringsystem ormonitoringdeviceisinoperative CFR60.7(f),Minn.R , Recordkeeping:ThePermiteeshalmaintainafileofalmeasurements,maintenance,reportsandrecordsforat subp.5(c),minn.r ,subp. leastfiveyears.thisrequirementismorestringentthan40cfrsection60.7(f),whichspecifiestwoyears Noowneroroperatorshalbuild,erect,instal,oruseanyarticle,machine,equipmentorprocess,theuseof whichconcealsanemissionwhichwouldotherwiseconstituteaviolationofanapplicablestandard. 40CFR60.12,Minn.R NitrogenOxides:Asrequiredin40CFR60.8,thePermiteeshalconductaninitialperformancetestwithin60 daysafterachievingthemaximum productionrateatwhichthefacilitywilbeoperated,butnolaterthe Permiteeshalconductaninitialperformancetest:Due180calendardaysafterInitialStartupDate.The performancetestshalbeconductedatworstcaseconditionsasdefinedatminn.r ,subp.2,using EPAReferenceMethod20,orothermethodapprovedbyMPCAintheperformancetestplanapproval. 40CFR (b)(2)(i),40CFR (c),Minn.R ,Minn. R ,Minn.R AgencyInterestName:NorthernNaturalGasCo-FaribaultCompressor ActivityNumber:IND

82 TSDRequirement(Printversion) SubjectItem ID Seq.# 29 Requirement EPAReferenceMethod20,orothermethodapprovedbyMPCAintheperformancetestplanapproval. EQUI5 30 NitrogenOxides:Whichevercomesfirst,thePermiteeshalconductaperformancetestevery8,760hoursor conductaperformancetest:dueafterinitialperformancetestdateevery36months.theperformancetest shalbeconductedatworstcaseconditionsasdefinedatminn.r ,subp.2,usingepareference Method20,orothermethodapprovedbyMPCAintheperformancetestplanapproval. 40CFR (b)(2)(i),40CFR (c),Minn.R ,Minn. R ,Minn.R CarbonMonoxide:Asrequiredin40CFR60.8,thePermiteeshalconductaninitialperformancetestwithin60 40CFR (b)(2)(i),40CFR daysafterachievingthemaximum productionrateatwhichthefacilitywilbeoperated,butnolaterthe (c),Minn.R ,Minn. Permiteeshalconductaninitialperformancetest:Due180calendardaysafterInitialStartupDate.The R ,Minn.R , performancetestshalbeconductedatworstcaseconditionsasdefinedatminn.r ,subp.2,using subp.1 EPAReferenceMethod10,orothermethodapprovedbyMPCAintheperformancetestplanapproval. 34 CarbonMonoxide:Whichevercomesfirst,thePermiteeshalconductaperformancetestevery8,760hoursor 40CFR (b)(2)(i),40CFR conductaperformancetest:dueafterinitialperformancetestdateevery36months.theperformancetest (c),Minn.R ,Minn. shalbeconductedatworstcaseconditionsasdefinedatminn.r ,subp.2,usingepareference R ,Minn.R , Method10,orothermethodapprovedbyMPCAintheperformancetestplanapproval. subp.1 35 VolatileOrganicCompounds:Asrequiredin40CFR60.8,thePermiteeshalconductaninitialperformance testwithin60daysafterachievingthemaximum productionrateatwhichthefacilitywilbeoperated,butnolater 40CFR (b)(2)(i),40CFR thepermiteeshalconductaninitialperformancetest:due180calendardaysafterinitialstartupdate.the (c),Minn.R ,Minn. performancetestshalbeconductedatworstcaseconditionsasdefinedatminn.r ,subp.2,using R ,Minn.R , EPAReferenceMethod18,25A,and320,orothermethodapprovedbyMPCAintheperformancetestplan subp.1 approval. 36 VolatileOrganicCompounds:Whichevercomesfirst,thePermiteeshalconductaperformancetestevery 8,760hoursorconductaperformancetest:DueafterInitialPerformanceTestDateevery36months.The performancetestshalbeconductedatworstcaseconditionsasdefinedatminn.r ,subp.2,using EPAReferenceMethod18,25A,and320,orothermethodapprovedbyMPCAintheperformancetestplan approval. 40CFR (b)(2)(i),40CFR (c),Minn.R ,Minn. R ,Minn.R , subp.1 37 ThePermiteeshalsubmitanotificationofdateconstructionbegan:Due30calendardaysafterDateof ConstructionStart.SubmitthenameandnumberoftheSubjectItem andthedateconstructionbegan. 40CFR60.7(a)(1),Minn.R ,subp.16(L),Minn.R ,subp.1 38 ThePermiteeshalsubmitanotificationoftheactualdateofinitialstartup:Due15calendardaysafterInitial StartupDate.SubmitthenameandnumberoftheSubjectItem andthedateofstartup.startupisasdefinedin Minn.R ,subp.42a. 40CFR60.7(a)(3),Minn.R ,subp.16(L),Minn.R ,subp.1 AgencyInterestName:NorthernNaturalGasCo-FaribaultCompressor ActivityNumber:IND

83 TSDRequirement(Printversion) SubjectItem ID Seq.# 38 Requirement Minn.R ,subp.42a. EQUI6 1 ParticulateMater<=0.40poundspermilionBtuheatinput(Thepotentialtoemitfrom theunitis lb/mmbtuduetoequipmentdesignandalowablefuels.). Minn.R ,subp.1 2 Opacity<=20percentopacityexceptforonesix-minuteperiodperhourofnotmorethan60percentopacity. Minn.R ,subp.2 3 ThePermiteeisauthorizedtoconstructandoperateEQUI6meetingthefolowingdesignrequirements,within 18monthsafterpermitissuanceofPermitNo Theunitshalmeetalapplicablerequirementsof thispermit. Minn.R ,subp.2 DesignRequirements; MMBtu/hrcapacity. EQUI7 1 ParticulateMater<=0.40poundspermilionBtuheatinput(Thepotentialtoemitfrom theunitis lb/mmbtuduetoequipmentdesignandalowablefuels.). Minn.R ,subp.1 2 Opacity<=20percentopacityexceptforonesix-minuteperiodperhourofnotmorethan60percentopacity. Minn.R ,subp.2 3 ThePermiteeisauthorizedtoconstructandoperateEQUI7meetingthefolowingdesignrequirements,within 18monthsafterpermitissuanceofPermitNo Theunitshalmeetalapplicablerequirementsof thispermit. Minn.R ,subp.2 DesignRequirements; MMBtu/hrcapacity. AgencyInterestName:NorthernNaturalGasCo-FaribaultCompressor ActivityNumber:IND

84 Attachment 3. Subject item inventory/details

85 Category Type ID Designation Description Groups Include In Permit Sort Order End Date Equipment Process Heater EQUI Heater 1 None Yes Equipment Process Heater EQUI Heater 2 None Yes Equipment Reciprocating IC Engine EQUI EU002 Emergency Generator None Yes Equipment Reciprocating IC Engine EQUI Reciprocating IC Engine None Yes Equipment Turbine EQUI EU001 Natural Gas Turbine COMG Yes Equipment Turbine EQUI Solar mars Turbine S COMG Yes Fugitive Equipment Leaks FUGI FS Flanges None Yes Fugitive Equipment Leaks FUGI FS002 1 Compressor Seal None Yes Fugitive Equipment Leaks FUGI FS Valves None Yes Structure Stack/Vent STRU SV001 Solar Mars Turbine 100 T15000S Stack None Yes Structure Stack/Vent STRU SV002 None Yes Structure Stack/Vent STRU Solar Mars Turbine S Stack None Yes Structure Stack/Vent STRU Caterpillar G3512 Generator Stack None Yes Structure Stack/Vent STRU Process Heater None Yes Structure Stack/Vent STRU Process Heater None Yes Total Facility Air Quality Total Facility TFAC Northern Natural Gas Co Faribault None Yes 1.00

86 Category Type ID Designation Description Components Include In Permit Sort Order Component Group Air Component Group COMG Limits to avoid Part 70 EQUI , EQUI Yes

87 Category Type ID Designation Description Sort Order AI Conventional site AISI

88 Attachment 4. Points Calculator

89 Points Calculator 1) AI ID No.: 1293 Total Points 65 2) Facility Name: Northern Natural Gas Co - Faribault Compressor 3) Small business? y/n? n 4) Air Project Tracking Numbers (including all ) Date of each Application Received: May 20, ) Final Permit No ) Permit Staff AW Total Total Application Type Air Project Tracking No. Tempo Activity ID Qty. Points Points Additionl Cost Details Administrative Amendment 1 0 $ - Minor Amendment 4 0 $ - Applicability Request 10 0 $ - Moderate Amendment 15 0 $ - Major Amendment 5568 IND $ 7, Individual State Permit (not reissuance) 50 0 $ - Individual Part 70 Permit (not reissuance) 75 0 $ - Additional Points Modeling Review 15 0 $ - BACT Review 15 0 $ - LAER Review 15 0 $ - CAA section 110(a)(2)(D)(i)(I) Review (i.e., Transport Rule/CAIR/CSAPR) 10 0 $ - Part 75 CEM analysis 10 0 $ - NSPS Review 5568 IND $ 5, KKKK, JJJJ NESHAP Review 5568 IND $ 2, ZZZZ Case-by-case MACT Review 20 0 $ - Netting 10 0 $ - Limits to remain below threshold 5568 IND $ 2, Part 70 Plantwide Applicability Limit (PAL) 20 0 $ - AERA review 15 0 $ - Variance request under $ - Confidentiality request under $ - EAW review 0 Part , subparts 18, item A; and $ - Part , 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 Part , subparts 4; 5 items A & B; 13; 15; 16, items B & C; and 17 item D 35 0 $ $ - Add'l Points 40 NOTES: (DQ Points)

90 Attachment 5. Manufacturer Information and Data to Support PTE Calculations

91 EQUI 1 Manufacturer Data to support Emission Factors

92

93

94

95

96

97

98 EQUI 2 Manufacturer Data to support Emission Factors

99

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102

103 EQUI 4 Manufacturer Data to support Emission Factors

104 SOLAR TURBINES INCORPORATED ENGINE PERFORMANCE CODE REV CUSTOMER: NNG JOB ID: Faribault DATE RUN: 16-Oct-15 RUN BY: Michael E Clay --- SUMMARY OF ENGINE EXHAUST ANALYSIS --- POINT NUMBER 1 HP=16696, %Full Load=100.0, Elev= 1000ft, %RH= 60.0, Temperature=-20.0F GENERAL INPUT SPECIFICATIONS ENGINE FUEL: SD NATURAL GAS in Hg AMBIENT PRESSURE 60.0 percent RELATIVE HUMIDITY SP. HUMIDITY (LBM H2O/LBM DRY AIR) FUEL GAS COMPOSITION (VOLUME PERCENT) LHV (Btu/Scf) = SG = (Btu/Scf) = Methane (CH4) = Ethane (C2H6) = Propane (C3H8) = N-Butane (C4H10) = N-Pentane (C5H12) = Hexane (C6H14) = Carbon Dioxide (CO2) = Hydrogen Sulfide (H2S) = Nitrogen (N2) = STANDARD CONDITIONS FOR GAS VOLUMES: Temperature: 60 deg F Pressure: in Hg NORMAL CONDITIONS FOR GAS VOLUMES: Temperature: 32 deg F Pressure: in Hg GENERAL OUTPUT DATA EXHAUST GAS ANALYSIS lbm/hr FUEL FLOW Scfm FUEL FLOW Btu/lbm LOWER HEATING VALUE 939. Btu/Scf LOWER HEATING VALUE Scfm EXHAUST 14.7 PSIA & 60F Acfm ACTUAL EXHAUST FLOW CFm lbm/hr EXHAUST GAS FLOW MOLECULAR WEIGHT OF EXHAUST GAS AIR/FUEL RATIO ARGON CO2 H2O N2 O VOLUME PERCENT WET VOLUME PERCENT DRY lbm/hr g/(g FUEL)

105 SOLAR TURBINES INCORPORATED ENGINE PERFORMANCE CODE REV CUSTOMER: NNG JOB ID: Faribault DATE RUN: 16-Oct-15 RUN BY: Michael E Clay --- SUMMARY OF ENGINE EXHAUST ANALYSIS --- POINT NUMBER 2 HP=16427, %Full Load=100.0, Elev= 1000ft, %RH= 60.0, Temperature= 0.0F GENERAL INPUT SPECIFICATIONS ENGINE FUEL: SD NATURAL GAS in Hg AMBIENT PRESSURE 60.0 percent RELATIVE HUMIDITY SP. HUMIDITY (LBM H2O/LBM DRY AIR) FUEL GAS COMPOSITION (VOLUME PERCENT) LHV (Btu/Scf) = SG = (Btu/Scf) = Methane (CH4) = Ethane (C2H6) = Propane (C3H8) = N-Butane (C4H10) = N-Pentane (C5H12) = Hexane (C6H14) = Carbon Dioxide (CO2) = Hydrogen Sulfide (H2S) = Nitrogen (N2) = STANDARD CONDITIONS FOR GAS VOLUMES: Temperature: 60 deg F Pressure: in Hg NORMAL CONDITIONS FOR GAS VOLUMES: Temperature: 32 deg F Pressure: in Hg!!! PLEASE, SUBMIT INQUIRY ON GAS FUEL SUITABILITY TO SAN DIEGO!!! GENERAL OUTPUT DATA EXHAUST GAS ANALYSIS lbm/hr FUEL FLOW Scfm FUEL FLOW Btu/lbm LOWER HEATING VALUE 939. Btu/Scf LOWER HEATING VALUE Scfm EXHAUST 14.7 PSIA & 60F Acfm ACTUAL EXHAUST FLOW CFm lbm/hr EXHAUST GAS FLOW MOLECULAR WEIGHT OF EXHAUST GAS AIR/FUEL RATIO ARGON CO2 H2O N2 O VOLUME PERCENT WET VOLUME PERCENT DRY lbm/hr g/(g FUEL)

106 SOLAR TURBINES INCORPORATED ENGINE PERFORMANCE CODE REV CUSTOMER: NNG JOB ID: Faribault DATE RUN: 16-Oct-15 RUN BY: Michael E Clay NEW EQUIPMENT PREDICTED EMISSION PERFORMANCE DATA FOR POINT NUMBER 2 Fuel: SD NATURAL GAS Customer: NNG Water Injection: NO Inquiry Number: SL Model: MARS S CS/MD STANDARD GAS Emissions Data: REV. 1.0 The following predicted emissions performance is based on the following specific single point: HP=16427, %Full Load=100.0, Elev= 1000ft, %RH= 60.0, Temperature= 0.0F NOX CO UHC PPMvd at 15% O ton/yr lbm/mmbtu (Fuel LHV) lbm/hr g/(hp-hr) (gas turbine shaft pwr) lbm/mmbtu (Fuel HHV) NOTES: 1. For short-term emission limits such as lbs/hr., Solar recommends using "worst case" anticipated operating conditions specific to the application and the site conditions. Worst case for one pollutant is not necessarily the same for another. 2. Solar's typical SoLoNOx warranty, for ppm values, is available for greater than 0 deg F or -20 deg C, and between 50% and 100% load or gas, fuel, and between 65% and 100% load for liquid fuel except for the Centaur 40). An emission warranty for non-solon x equipment is available for greater than 0 deg F or -20 deg C an 3. Fuel must meet Solar standard fuel specification ES Emissions are based on the attached fuel composition, or, San Diego natural gas or equivalent. 4. If needed, Solar can provide Product Information Letters to address turbine operation outside typical warranty ranges, as well as nonwarranted emissions of SO2, PM10/2.5, VOC, and formaldehyde. 5. Solar can provide factory testing in San Diego to ensure the actual unit(s) meet the above values within the tolerances quoted. Pricing and schedule impact will be provided upon request. 6. Any emissions warranty is applicable only for steady-state conditions and does not apply during start-up, shut-down, malfunction, or transient event.

107 SOLAR TURBINES INCORPORATED ENGINE PERFORMANCE CODE REV CUSTOMER: NNG JOB ID: Faribault DATE RUN: 16-Oct-15 RUN BY: Michael E Clay --- SUMMARY OF ENGINE EXHAUST ANALYSIS --- POINT NUMBER 3 HP=15272, %Full Load=100.0, Elev= 1000ft, %RH= 60.0, Temperature= 40.0F GENERAL INPUT SPECIFICATIONS ENGINE FUEL: SD NATURAL GAS in Hg AMBIENT PRESSURE 60.0 percent RELATIVE HUMIDITY SP. HUMIDITY (LBM H2O/LBM DRY AIR) FUEL GAS COMPOSITION (VOLUME PERCENT) LHV (Btu/Scf) = SG = (Btu/Scf) = Methane (CH4) = Ethane (C2H6) = Propane (C3H8) = N-Butane (C4H10) = N-Pentane (C5H12) = Hexane (C6H14) = Carbon Dioxide (CO2) = Hydrogen Sulfide (H2S) = Nitrogen (N2) = STANDARD CONDITIONS FOR GAS VOLUMES: Temperature: 60 deg F Pressure: in Hg NORMAL CONDITIONS FOR GAS VOLUMES: Temperature: 32 deg F Pressure: in Hg!!! PLEASE, SUBMIT INQUIRY ON GAS FUEL SUITABILITY TO SAN DIEGO!!! GENERAL OUTPUT DATA EXHAUST GAS ANALYSIS lbm/hr FUEL FLOW Scfm FUEL FLOW Btu/lbm LOWER HEATING VALUE 939. Btu/Scf LOWER HEATING VALUE Scfm EXHAUST 14.7 PSIA & 60F Acfm ACTUAL EXHAUST FLOW CFm lbm/hr EXHAUST GAS FLOW MOLECULAR WEIGHT OF EXHAUST GAS AIR/FUEL RATIO ARGON CO2 H2O N2 O VOLUME PERCENT WET VOLUME PERCENT DRY lbm/hr g/(g FUEL)

108 SOLAR TURBINES INCORPORATED ENGINE PERFORMANCE CODE REV CUSTOMER: NNG JOB ID: Faribault DATE RUN: 16-Oct-15 RUN BY: Michael E Clay NEW EQUIPMENT PREDICTED EMISSION PERFORMANCE DATA FOR POINT NUMBER 3 Fuel: SD NATURAL GAS Customer: NNG Water Injection: NO Inquiry Number: SL Model: MARS S CS/MD STANDARD GAS Emissions Data: REV. 1.0 The following predicted emissions performance is based on the following specific single point: HP=15272, %Full Load=100.0, Elev= 1000ft, %RH= 60.0, Temperature= 40.0F NOX CO UHC PPMvd at 15% O ton/yr lbm/mmbtu (Fuel LHV) lbm/hr g/(hp-hr) (gas turbine shaft pwr) lbm/mmbtu (Fuel HHV) NOTES: 1. For short-term emission limits such as lbs/hr., Solar recommends using "worst case" anticipated operating conditions specific to the application and the site conditions. Worst case for one pollutant is not necessarily the same for another. 2. Solar's typical SoLoNOx warranty, for ppm values, is available for greater than 0 deg F or -20 deg C, and between 50% and 100% load or gas, fuel, and between 65% and 100% load for liquid fuel except for the Centaur 40). An emission warranty for non-solon x equipment is available for greater than 0 deg F or -20 deg C an 3. Fuel must meet Solar standard fuel specification ES Emissions are based on the attached fuel composition, or, San Diego natural gas or equivalent. 4. If needed, Solar can provide Product Information Letters to address turbine operation outside typical warranty ranges, as well as nonwarranted emissions of SO2, PM10/2.5, VOC, and formaldehyde. 5. Solar can provide factory testing in San Diego to ensure the actual unit(s) meet the above values within the tolerances quoted. Pricing and schedule impact will be provided upon request. 6. Any emissions warranty is applicable only for steady-state conditions and does not apply during start-up, shut-down, malfunction, or transient event.

109 SOLAR TURBINES INCORPORATED ENGINE PERFORMANCE CODE REV CUSTOMER: NNG JOB ID: Faribault DATE RUN: 16-Oct-15 RUN BY: Michael E Clay --- SUMMARY OF ENGINE EXHAUST ANALYSIS --- POINT NUMBER 4 HP=14459, %Full Load=100.0, Elev= 1000ft, %RH= 60.0, Temperature= 60.0F GENERAL INPUT SPECIFICATIONS ENGINE FUEL: SD NATURAL GAS in Hg AMBIENT PRESSURE 60.0 percent RELATIVE HUMIDITY SP. HUMIDITY (LBM H2O/LBM DRY AIR) FUEL GAS COMPOSITION (VOLUME PERCENT) LHV (Btu/Scf) = SG = (Btu/Scf) = Methane (CH4) = Ethane (C2H6) = Propane (C3H8) = N-Butane (C4H10) = N-Pentane (C5H12) = Hexane (C6H14) = Carbon Dioxide (CO2) = Hydrogen Sulfide (H2S) = Nitrogen (N2) = STANDARD CONDITIONS FOR GAS VOLUMES: Temperature: 60 deg F Pressure: in Hg NORMAL CONDITIONS FOR GAS VOLUMES: Temperature: 32 deg F Pressure: in Hg!!! PLEASE, SUBMIT INQUIRY ON GAS FUEL SUITABILITY TO SAN DIEGO!!! GENERAL OUTPUT DATA EXHAUST GAS ANALYSIS lbm/hr FUEL FLOW Scfm FUEL FLOW Btu/lbm LOWER HEATING VALUE 939. Btu/Scf LOWER HEATING VALUE Scfm EXHAUST 14.7 PSIA & 60F Acfm ACTUAL EXHAUST FLOW CFm lbm/hr EXHAUST GAS FLOW MOLECULAR WEIGHT OF EXHAUST GAS AIR/FUEL RATIO ARGON CO2 H2O N2 O VOLUME PERCENT WET VOLUME PERCENT DRY lbm/hr g/(g FUEL)

110 SOLAR TURBINES INCORPORATED ENGINE PERFORMANCE CODE REV CUSTOMER: NNG JOB ID: Faribault DATE RUN: 16-Oct-15 RUN BY: Michael E Clay NEW EQUIPMENT PREDICTED EMISSION PERFORMANCE DATA FOR POINT NUMBER 4 Fuel: SD NATURAL GAS Customer: NNG Water Injection: NO Inquiry Number: SL Model: MARS S CS/MD STANDARD GAS Emissions Data: REV. 1.0 The following predicted emissions performance is based on the following specific single point: HP=14459, %Full Load=100.0, Elev= 1000ft, %RH= 60.0, Temperature= 60.0F NOX CO UHC PPMvd at 15% O ton/yr lbm/mmbtu (Fuel LHV) lbm/hr g/(hp-hr) (gas turbine shaft pwr) lbm/mmbtu (Fuel HHV) NOTES: 1. For short-term emission limits such as lbs/hr., Solar recommends using "worst case" anticipated operating conditions specific to the application and the site conditions. Worst case for one pollutant is not necessarily the same for another. 2. Solar's typical SoLoNOx warranty, for ppm values, is available for greater than 0 deg F or -20 deg C, and between 50% and 100% load or gas, fuel, and between 65% and 100% load for liquid fuel except for the Centaur 40). An emission warranty for non-solon x equipment is available for greater than 0 deg F or -20 deg C an 3. Fuel must meet Solar standard fuel specification ES Emissions are based on the attached fuel composition, or, San Diego natural gas or equivalent. 4. If needed, Solar can provide Product Information Letters to address turbine operation outside typical warranty ranges, as well as nonwarranted emissions of SO2, PM10/2.5, VOC, and formaldehyde. 5. Solar can provide factory testing in San Diego to ensure the actual unit(s) meet the above values within the tolerances quoted. Pricing and schedule impact will be provided upon request. 6. Any emissions warranty is applicable only for steady-state conditions and does not apply during start-up, shut-down, malfunction, or transient event.

111 SOLAR TURBINES INCORPORATED ENGINE PERFORMANCE CODE REV CUSTOMER: NNG JOB ID: Faribault DATE RUN: 16-Oct-15 RUN BY: Michael E Clay --- SUMMARY OF ENGINE EXHAUST ANALYSIS --- POINT NUMBER 5 HP=13435, %Full Load=100.0, Elev= 1000ft, %RH= 60.0, Temperature= 80.0F GENERAL INPUT SPECIFICATIONS ENGINE FUEL: SD NATURAL GAS in Hg AMBIENT PRESSURE 60.0 percent RELATIVE HUMIDITY SP. HUMIDITY (LBM H2O/LBM DRY AIR) FUEL GAS COMPOSITION (VOLUME PERCENT) LHV (Btu/Scf) = SG = (Btu/Scf) = Methane (CH4) = Ethane (C2H6) = Propane (C3H8) = N-Butane (C4H10) = N-Pentane (C5H12) = Hexane (C6H14) = Carbon Dioxide (CO2) = Hydrogen Sulfide (H2S) = Nitrogen (N2) = STANDARD CONDITIONS FOR GAS VOLUMES: Temperature: 60 deg F Pressure: in Hg NORMAL CONDITIONS FOR GAS VOLUMES: Temperature: 32 deg F Pressure: in Hg!!! PLEASE, SUBMIT INQUIRY ON GAS FUEL SUITABILITY TO SAN DIEGO!!! GENERAL OUTPUT DATA EXHAUST GAS ANALYSIS lbm/hr FUEL FLOW Scfm FUEL FLOW Btu/lbm LOWER HEATING VALUE 939. Btu/Scf LOWER HEATING VALUE Scfm EXHAUST 14.7 PSIA & 60F Acfm ACTUAL EXHAUST FLOW CFm lbm/hr EXHAUST GAS FLOW MOLECULAR WEIGHT OF EXHAUST GAS AIR/FUEL RATIO ARGON CO2 H2O N2 O VOLUME PERCENT WET VOLUME PERCENT DRY lbm/hr g/(g FUEL)

112 SOLAR TURBINES INCORPORATED ENGINE PERFORMANCE CODE REV CUSTOMER: NNG JOB ID: Faribault DATE RUN: 16-Oct-15 RUN BY: Michael E Clay NEW EQUIPMENT PREDICTED EMISSION PERFORMANCE DATA FOR POINT NUMBER 5 Fuel: SD NATURAL GAS Customer: NNG Water Injection: NO Inquiry Number: SL Model: MARS S CS/MD STANDARD GAS Emissions Data: REV. 1.0 The following predicted emissions performance is based on the following specific single point: HP=13435, %Full Load=100.0, Elev= 1000ft, %RH= 60.0, Temperature= 80.0F NOX CO UHC PPMvd at 15% O ton/yr lbm/mmbtu (Fuel LHV) lbm/hr g/(hp-hr) (gas turbine shaft pwr) lbm/mmbtu (Fuel HHV) NOTES: 1. For short-term emission limits such as lbs/hr., Solar recommends using "worst case" anticipated operating conditions specific to the application and the site conditions. Worst case for one pollutant is not necessarily the same for another. 2. Solar's typical SoLoNOx warranty, for ppm values, is available for greater than 0 deg F or -20 deg C, and between 50% and 100% load or gas, fuel, and between 65% and 100% load for liquid fuel except for the Centaur 40). An emission warranty for non-solon x equipment is available for greater than 0 deg F or -20 deg C an 3. Fuel must meet Solar standard fuel specification ES Emissions are based on the attached fuel composition, or, San Diego natural gas or equivalent. 4. If needed, Solar can provide Product Information Letters to address turbine operation outside typical warranty ranges, as well as nonwarranted emissions of SO2, PM10/2.5, VOC, and formaldehyde. 5. Solar can provide factory testing in San Diego to ensure the actual unit(s) meet the above values within the tolerances quoted. Pricing and schedule impact will be provided upon request. 6. Any emissions warranty is applicable only for steady-state conditions and does not apply during start-up, shut-down, malfunction, or transient event.

113 SOLAR TURBINES INCORPORATED ENGINE PERFORMANCE CODE REV CUSTOMER: NNG JOB ID: Faribault DATE RUN: 16-Oct-15 RUN BY: Michael E Clay --- SUMMARY OF ENGINE EXHAUST ANALYSIS --- POINT NUMBER 6 HP=12303, %Full Load=100.0, Elev= 1000ft, %RH= 60.0, Temperature=100.0F GENERAL INPUT SPECIFICATIONS ENGINE FUEL: SD NATURAL GAS in Hg AMBIENT PRESSURE 60.0 percent RELATIVE HUMIDITY SP. HUMIDITY (LBM H2O/LBM DRY AIR) FUEL GAS COMPOSITION (VOLUME PERCENT) LHV (Btu/Scf) = SG = (Btu/Scf) = Methane (CH4) = Ethane (C2H6) = Propane (C3H8) = N-Butane (C4H10) = N-Pentane (C5H12) = Hexane (C6H14) = Carbon Dioxide (CO2) = Hydrogen Sulfide (H2S) = Nitrogen (N2) = STANDARD CONDITIONS FOR GAS VOLUMES: Temperature: 60 deg F Pressure: in Hg NORMAL CONDITIONS FOR GAS VOLUMES: Temperature: 32 deg F Pressure: in Hg!!! PLEASE, SUBMIT INQUIRY ON GAS FUEL SUITABILITY TO SAN DIEGO!!! GENERAL OUTPUT DATA EXHAUST GAS ANALYSIS lbm/hr FUEL FLOW Scfm FUEL FLOW Btu/lbm LOWER HEATING VALUE 939. Btu/Scf LOWER HEATING VALUE Scfm EXHAUST 14.7 PSIA & 60F Acfm ACTUAL EXHAUST FLOW CFm lbm/hr EXHAUST GAS FLOW MOLECULAR WEIGHT OF EXHAUST GAS AIR/FUEL RATIO ARGON CO2 H2O N2 O VOLUME PERCENT WET VOLUME PERCENT DRY lbm/hr g/(g FUEL)

114 SOLAR TURBINES INCORPORATED ENGINE PERFORMANCE CODE REV CUSTOMER: NNG JOB ID: Faribault DATE RUN: 16-Oct-15 RUN BY: Michael E Clay NEW EQUIPMENT PREDICTED EMISSION PERFORMANCE DATA FOR POINT NUMBER 6 Fuel: SD NATURAL GAS Customer: NNG Water Injection: NO Inquiry Number: SL Model: MARS S CS/MD STANDARD GAS Emissions Data: REV. 1.0 The following predicted emissions performance is based on the following specific single point: HP=12303, %Full Load=100.0, Elev= 1000ft, %RH= 60.0, Temperature=100.0F NOX CO UHC PPMvd at 15% O ton/yr lbm/mmbtu (Fuel LHV) lbm/hr g/(hp-hr) (gas turbine shaft pwr) lbm/mmbtu (Fuel HHV) NOTES: 1. For short-term emission limits such as lbs/hr., Solar recommends using "worst case" anticipated operating conditions specific to the application and the site conditions. Worst case for one pollutant is not necessarily the same for another. 2. Solar's typical SoLoNOx warranty, for ppm values, is available for greater than 0 deg F or -20 deg C, and between 50% and 100% load or gas, fuel, and between 65% and 100% load for liquid fuel except for the Centaur 40). An emission warranty for non-solon x equipment is available for greater than 0 deg F or -20 deg C an 3. Fuel must meet Solar standard fuel specification ES Emissions are based on the attached fuel composition, or, San Diego natural gas or equivalent. 4. If needed, Solar can provide Product Information Letters to address turbine operation outside typical warranty ranges, as well as nonwarranted emissions of SO2, PM10/2.5, VOC, and formaldehyde. 5. Solar can provide factory testing in San Diego to ensure the actual unit(s) meet the above values within the tolerances quoted. Pricing and schedule impact will be provided upon request. 6. Any emissions warranty is applicable only for steady-state conditions and does not apply during start-up, shut-down, malfunction, or transient event.

115 SOLAR TURBINES INCORPORATED ENGINE PERFORMANCE CODE REV CUSTOMER: NNG JOB ID: Faribault DATE RUN: 16-Oct-15 RUN BY: Michael E Clay MARS S CS/MD STANDARD GAS TMG-2S REV. 1.0 DATA FOR MINIMUM PERFORMANCE Fuel Type SD NATURAL GAS Elevation feet 1000 Inlet Loss in H2O 4.0 Exhaust Loss in H2O 4.0 Accessory on GP Shaft HP 27.8 Engine Inlet Temp.** deg F Relative Humidity % Elevation Loss HP Inlet Loss HP Exhaust Loss HP Driven Equipment Speed RPM Optimum Equipment Speed RPM Gas Generator Speed RPM Specified Load HP FULL FULL FULL FULL FULL FULL Net Output Power HP Fuel Flow mmbtu/hr Heat Rate Btu/HP-hr Therm Eff % Inlet Air Flow lbm/hr Engine Exhaust Flow lbm/hr PCD psig Compensated PTIT deg F PT Exit Temperature deg F Exhaust Temperature deg F FUEL GAS COMPOSITION (VOLUME PERCENT) LHV (Btu/Scf) = SG = (Btu/Scf) = Methane (CH4) = Ethane (C2H6) = Propane (C3H8) = N-Butane (C4H10) = N-Pentane (C5H12) = Hexane (C6H14) = Carbon Dioxide (CO2) = Hydrogen Sulfide (H2S) = Nitrogen (N2) = STANDARD CONDITIONS FOR GAS VOLUMES: Temperature: 60 deg F Pressure: in Hg NORMAL CONDITIONS FOR GAS VOLUMES: Temperature: 32 deg F Pressure: in Hg

116 !!! PLEASE, SUBMIT INQUIRY ON GAS FUEL SUITABILITY TO SAN DIEGO!!! This performance was calculated with a basic inlet and exhaust system. Special equipment such as low noise silencers, special filters, heat recovery systems or cooling devices will affect engine performance. Performance shown is "Expected" performance at the pressure drops stated, not guaranteed. **Cannot guarantee emissions with ambient temperature below 0 deg F. Please submit SER for this application.

117 PREDICTED EMISSION PERFORMANCE Customer NNG Job ID Faribault Inquiry Number SL Run By Date Run Michael E Clay 16-Oct-15 Engine Model MARS S CS/MD STANDARD Fuel Type Water Injection SD NATURAL GAS NO Engine Emissions Data REV. 1.0 NOx EMISSIONS CO EMISSIONS UHC EMISSIONS HP 100.0% Load Elev ft Rel. Humidity 60.0% Temperature 0 Deg. F PPMvd at 15% O ton/yr lbm/mmbtu (Fuel LHV) lbm/hr g/(hp-hr) (gas turbine shaft pwr) lbm/mmbtu (Fuel HHV) HP 100.0% Load Elev ft Rel. Humidity 60.0% Temperature 40.0 Deg. F PPMvd at 15% O ton/yr lbm/mmbtu (Fuel LHV) lbm/hr g/(hp-hr) (gas turbine shaft pwr) lbm/mmbtu (Fuel HHV) Notes 1. For short-term emission limits such as lbs/hr., Solar recommends using "worst case" anticipated operating conditions specific to the application and the site conditions. Worst case for one pollutant is not necessarily the same for another. 2. Solar s typical SoLoNOx warranty, for ppm values, is available for greater than 0 deg F or -20 deg C, and between 50% and 100% load for gas, fuel, and between 65% and 100% load for liquid fuel (except f or the Centaur 40). An emission warranty for non-solonox equipment is available for greater than 0 deg F or -20 deg C and betwee 3. Fuel must meet Solar standard fuel specification ES Emissions are based on the attached fuel composition, or, San Diego natural gas or equivalent. 4. If needed, Solar can provide Product Information Letters to address turbine operation outside typical warranty ranges, as well as non-warranted emissions of SO2, PM10/2.5, VOC, and formaldehyde. 5. Solar can provide factory testing in San Diego to ensure the actual unit(s) meet the above values within the tolerances quoted. Pricing and schedule impact will be provided upon request. 6. Any emissions warranty is applicable only for steady-state conditions and does not apply during start-up, shut-down, malfunction, or transient event.

118 PREDICTED EMISSION PERFORMANCE Customer NNG Job ID Faribault Inquiry Number SL Run By Date Run Michael E Clay 16-Oct-15 Engine Model MARS S CS/MD STANDARD Fuel Type Water Injection SD NATURAL GAS NO Engine Emissions Data REV. 1.0 NOx EMISSIONS CO EMISSIONS UHC EMISSIONS HP 100.0% Load Elev ft Rel. Humidity 60.0% Temperature 60.0 Deg. F PPMvd at 15% O ton/yr lbm/mmbtu (Fuel LHV) lbm/hr g/(hp-hr) (gas turbine shaft pwr) lbm/mmbtu (Fuel HHV) HP 100.0% Load Elev ft Rel. Humidity 60.0% Temperature 80.0 Deg. F PPMvd at 15% O ton/yr lbm/mmbtu (Fuel LHV) lbm/hr g/(hp-hr) (gas turbine shaft pwr) lbm/mmbtu (Fuel HHV) Notes 1. For short-term emission limits such as lbs/hr., Solar recommends using "worst case" anticipated operating conditions specific to the application and the site conditions. Worst case for one pollutant is not necessarily the same for another. 2. Solar s typical SoLoNOx warranty, for ppm values, is available for greater than 0 deg F or -20 deg C, and between 50% and 100% load for gas, fuel, and between 65% and 100% load for liquid fuel (except f or the Centaur 40). An emission warranty for non-solonox equipment is available for greater than 0 deg F or -20 deg C and betwee 3. Fuel must meet Solar standard fuel specification ES Emissions are based on the attached fuel composition, or, San Diego natural gas or equivalent. 4. If needed, Solar can provide Product Information Letters to address turbine operation outside typical warranty ranges, as well as non-warranted emissions of SO2, PM10/2.5, VOC, and formaldehyde. 5. Solar can provide factory testing in San Diego to ensure the actual unit(s) meet the above values within the tolerances quoted. Pricing and schedule impact will be provided upon request. 6. Any emissions warranty is applicable only for steady-state conditions and does not apply during start-up, shut-down, malfunction, or transient event.

119 PREDICTED EMISSION PERFORMANCE Customer NNG Job ID Faribault Inquiry Number SL Run By Date Run Michael E Clay 16-Oct-15 Engine Model MARS S CS/MD STANDARD Fuel Type Water Injection SD NATURAL GAS NO Engine Emissions Data REV. 1.0 NOx EMISSIONS CO EMISSIONS UHC EMISSIONS HP 100.0% Load Elev ft Rel. Humidity 60.0% Temperature Deg. F PPMvd at 15% O ton/yr lbm/mmbtu (Fuel LHV) lbm/hr g/(hp-hr) (gas turbine shaft pwr) lbm/mmbtu (Fuel HHV) Notes 1. For short-term emission limits such as lbs/hr., Solar recommends using "worst case" anticipated operating conditions specific to the application and the site conditions. Worst case for one pollutant is not necessarily the same for another. 2. Solar s typical SoLoNOx warranty, for ppm values, is available for greater than 0 deg F or -20 deg C, and between 50% and 100% load for gas, fuel, and between 65% and 100% load for liquid fuel (except f or the Centaur 40). An emission warranty for non-solonox equipment is available for greater than 0 deg F or -20 deg C and betwee 3. Fuel must meet Solar standard fuel specification ES Emissions are based on the attached fuel composition, or, San Diego natural gas or equivalent. 4. If needed, Solar can provide Product Information Letters to address turbine operation outside typical warranty ranges, as well as non-warranted emissions of SO2, PM10/2.5, VOC, and formaldehyde. 5. Solar can provide factory testing in San Diego to ensure the actual unit(s) meet the above values within the tolerances quoted. Pricing and schedule impact will be provided upon request. 6. Any emissions warranty is applicable only for steady-state conditions and does not apply during start-up, shut-down, malfunction, or transient event.

120 PREDICTED ENGINE PERFORMANCE Customer NNG Job ID Faribault Run By Date Run Michael E Clay 16-Oct-15 Engine Performance Code Engine Performance Data REV REV. 1.0 Model MARS S Package Type CS/MD Match STANDARD Fuel System GAS Fuel Type SD NATURAL GAS DATA FOR MINIMUM PERFORMANCE Elevation feet 1000 Inlet Loss in H2O 4.0 Exhaust Loss in H2O 4.0 Accessory on GP Shaft HP Engine Inlet Temperature deg F Relative Humidity % Driven Equipment Speed RPM Specified Load HP FULL FULL FULL FULL FULL FULL Net Output Power HP Fuel Flow mmbtu/hr Heat Rate Btu/HP-hr Therm Eff % Engine Exhaust Flow lbm/hr PT Exit Temperature deg F Exhaust Temperature deg F Fuel Gas Composition (Volume Percent) Methane (CH4) Ethane (C2H6) 4.16 Propane (C3H8) 0.84 N-Butane (C4H10) 0.18 N-Pentane (C5H12) 0.04 Hexane (C6H14) 0.04 Carbon Dioxide (CO2) 0.44 Hydrogen Sulfide (H2S) Nitrogen (N2) 1.51 Fuel Gas Properties LHV (Btu/Scf) Specific Gravity Wobbe Index at 60F This performance was calculated with a basic inlet and exhaust system. Special equipment such as low noise silencers, special filters, heat recovery systems or cooling devices will affect engine performance. Performance shown is "Expected" performance at the pressure drops stated, not guaranteed.

121 EQUI 5 Manufacturer Data to support Emission Factors

122 G3512 GAS ENGINE TECHNICAL DATA ENGINE SPEED (rpm): 1800 RATING STRATEGY: STANDARD COMPRESSION RATIO: 9.7:1 APPLICATION: PACKAGED GENSET AFTERCOOLER TYPE: SCAC RATING LEVEL: STANDBY AFTERCOOLER - STAGE 2 INLET (ºF): 130 FUEL: NAT GAS AFTERCOOLER - STAGE 1 INLET (ºF): 190 FUEL SYSTEM: CAT LOW PRESSURE JACKET WATER OUTLET (ºF): 210 WITH AIR FUEL RATIO CONTROL ASPIRATION: TA FUEL PRESSURE RANGE (psig): COOLING SYSTEM: JW+OC+1AC, 2AC FUEL METHANE NUMBER: 85 CONTROL SYSTEM: ADEM4 W/ IM FUEL LHV (Btu/scf): 905 EXHAUST MANIFOLD: DRY ALTITUDE CAPABILITY AT 77ºF INLET AIR TEMP. (ft): 4114 COMBUSTION: LOW EMISSION POWER FACTOR: 0.8 NOx EMISSION LEVEL (g/bhp-hr NOx): 2.0 VOLTAGE (V): FAN POWER (BHP): 47 RATING NOTES LOAD 100% 75% 50% PACKAGE POWER (WITH FAN) (1) (2) ekw 750 PACKAGE POWER (WITH FAN) (1) (2) KVA 938 ENGINE POWER (WITHOUT FAN) (2) bhp 1102 GENERATOR EFFICIENCY (1) % 95.3 PACKAGE EFFICIENCY (@ 0.8 Power Factor) (ISO 3046/1) (3) % 33.5 THERMAL EFFICIENCY (4) % 50.5 TOTAL EFFICIENCY (@ 0.8 Power Factor) (5) % 84.0 ENGINE DATA PACKAGE FUEL CONSUMPTION (ISO 3046/1) (6) Btu/ekw-hr PACKAGE FUEL CONSUMPTION (NOMINAL) (6) Btu/ekw-hr ENGINE FUEL CONSUMPTION (NOMINAL) (6) Btu/bhp-hr 7059 AIR FLOW (77ºF, 14.7 psia) (WET) (7) (8) ft3/min 2388 AIR FLOW (WET) (7) (8) lb/hr FUEL FLOW (60ºF, 14.7 psia) scfm 143 COMPRESSOR OUT PRESSURE in HG(abs) 69.1 COMPRESSOR OUT TEMPERATURE ºF 280 AFTERCOOLER AIR OUT TEMPERATURE ºF 138 INLET MAN. PRESSURE (9) in HG(abs) 61.6 INLET MAN. TEMPERATURE (MEASURED IN PLENUM) (10) ºF 137 TIMING (11) ºBTDC 32 EXHAUST TEMPERATURE - ENGINE OUTLET (12) ºF 991 EXHAUST GAS FLOW (@engine outlet temp, 14.5 psia) (WET) (13) (8) ft3/min 6959 EXHAUST GAS MASS FLOW (WET) (13) (8) lb/hr EMISSIONS DATA - ENGINE OUT NOx (as NO2) (14) (15) g/bhp-hr 2.00 CO (14) (16) g/bhp-hr 1.86 THC (mol. wt. of 15.84) (14) (16) g/bhp-hr 2.26 NMHC (mol. wt. of 15.84) (14) (16) g/bhp-hr 0.34 NMNEHC (VOCs) (mol. wt. of 15.84) (14) (16) (17) g/bhp-hr 0.23 HCHO (Formaldehyde) (14) (16) g/bhp-hr 0.38 CO2 (14) (16) g/bhp-hr 500 EXHAUST OXYGEN (14) (18) % DRY 9.2 LAMBDA (14) (18) 1.70 ENERGY BALANCE DATA LHV INPUT (19) Btu/min HEAT REJECTION TO JACKET WATER (JW) (20) (28) Btu/min HEAT REJECTION TO ATMOSPHERE (21) Btu/min 4871 HEAT REJECTION TO LUBE OIL (OC) (22) (28) Btu/min 5481 HEAT REJECTION TO EXHAUST (LHV TO 77ºF) (23) (24) Btu/min HEAT REJECTION TO EXHAUST (LHV TO 248ºF) (23) Btu/min HEAT REJECTION TO A/C - STAGE 1 (1AC) (25) (28) Btu/min 3259 HEAT REJECTION TO A/C - STAGE 2 (2AC) (26) (29) Btu/min 2811 PUMP POWER (27) Btu/min 971 CONDITIONS AND DEFINITIONS Engine rating obtained and presented in accordance with ISO 3046/1. Standard reference conditions of 77ºF, IN HG barometric pressure. No overload permitted at rating shown. Consult the altitude deration factor chart for applications that exceed the rated altitude or temperature. Emission levels are at engine exhaust flange prior to any after treatment. Values are based on engine operating at steady state conditions, adjusted to the specified NOx level as 100% load. Tolerances are dependent upon fuel quality. Fuel methane number cannot vary more than ± 3. Published part load data is with air fuel ratio control. For notes information consult page 3. The engine technical performance data listed above is preliminary in nature and can change as the development program for this new product progresses. This data represents Caterpillar's best knowledge to date on this product but carries no guarantees or warranty, either expressed or implied. This data will be superseded by the final production data when the product completes the development program and the production data is published in TMI. This data should not be used for final designs, sizing, purchase of equipment or financial calculations as it is subject to change. Data generated by Gas Engine Data Master Version Ref. Data Set G , Printed 7/29/2015 Page 1 of 3

123 G3512 GAS ENGINE TECHNICAL DATA FUEL USAGE GUIDE: This table shows the derate factor and full load set point timing required for a given fuel. Note that deration and set point timing reduction may be required as the methane number decreases. Methane number is a scale to measure detonation characteristics of various fuels. The methane number of a fuel is determined by using the Caterpillar methane number calculation program. ALTITUDE DERATION FACTORS: This table shows the deration required for various air inlet temperatures and altitudes. Use this information along with the fuel usage guide chart to help determine actual engine power for your site. ACTUAL ENGINE RATING: To determine the actual rating of the engine at site conditions, one must consider seperately, limitations due to fuel characteristics and air system limitations. The fuel usage guide deration establishes fuel limitations. The altitude/temperature deration factors and the RPC (reference to the Caterpillar Methane Program) establish air system limitations. RPC comes into play when the altitude/temperature deration is less than 1.0 (100%). Under this condition, add the two factors together. When the site conditions do not require an altitude/temperature derate (factor is 1.0), it is assumed the turbocharger has sufficient capability to overcome the low fuel relative power, and RPC is ignored. To determine the actual power available, take the lowest factor between 1) and 2). 1) Fuel usage Guide Deration 2) 1-((1-Altitude/Temperature Deration) + (1-RPC)) AFTERCOOLER HEAT REJECTION FACTORS(ACHRF): To maintain a constant air inlet manifold temperature, as the inlet air temperature goes up, so must the heat rejection. As altitude increases, the turbocharger must work harder to overcome the lower atmospheric pressure. This increases the amount of heat that must be removed from the inlet air by the aftercooler. Use the aftercooler heat rejection factor (ACHRF) to adjust for inlet air temp and altitude conditions. See notes 28 and 29 for application of this factor in calculating the heat exchanger sizing criteria. Failure to properly account for these factors could result in detonation and cause the engine to shutdown or fail. NOTES: 1. Generator efficiencies, power factor, and voltage are based on standard generator. [Package Power (ekw) is calculated as: (Engine Power (bkw) - Fan Power (bkw)) x Generator Efficiency], [Package Power (kva) is calculated as: (Engine Power (bkw) - Fan Power (bkw)) x Generator Efficiency / Power Factor] 2. Rating is with two engine driven water pumps. Tolerance is (+)3, (-)0% of full load. 3. Package Efficiency published in accordance with ISO 3046/1, based on a 0.8 power factor. 4. Thermal Efficiency is calculated based on energy recovery from the jacket water, lube oil, 1st stage aftercooler, and exhaust to 248ºF with engine operation at ISO 3046/1 Package Efficiency, and assumes unburned fuel is converted in an oxidation catalyst. 5. Total efficiency is calculated as: Package Efficiency + Thermal Efficiency. Tolerance is ±10% of full load data. 6. ISO 3046/1 Package fuel consumption tolerance is (+)5, (-)0% at the specified power factor. Nominal package and engine fuel consumption tolerance is ± 3.0% of full load data at the specified power factor. 7. Air flow value is on a 'wet' basis. Flow is a nominal value with a tolerance of ± 5 %. 8. Inlet and Exhaust Restrictions must not exceed A&I limits based on full load flow rates from the standard technical data sheet. 9. Inlet manifold pressure is a nominal value with a tolerance of ± 5 %. 10. Inlet manifold temperature is a nominal value with a tolerance of ± 9 F. 11. Timing indicated is for use with the minimum fuel methane number specified. Consult the appropriate fuel usage guide for timing at other methane numbers. 12. Exhaust temperature is a nominal value with a tolerance of (+)63 F, (-)54 F. 13. Exhaust flow value is on a 'wet' basis. Flow is a nominal value with a tolerance of ± 6 %. 14. Emissions data is at engine exhaust flange prior to any after treatment. 15. NOx values are "Not to Exceed". 16. CO, CO2, THC, NMHC, NMNEHC, and HCHO values are "Not to Exceed" levels. THC, NMHC, and NMNEHC do not include aldehydes. An oxidation catalyst may be required to meet Federal, State or local CO or HC requirements. 17. VOCs - Volatile organic compounds as defined in US EPA 40 CFR 60, subpart JJJJ 18. Exhaust Oxygen tolerance is ± 0.5; Lambda tolerance is ± Lambda and Exhaust Oxygen level are the result of adjusting the engine to operate at the specified NOx level. 19. LHV rate tolerance is ± 3.0%. 20. Heat rejection to jacket water value displayed includes heat to jacket water alone. Value is based on treated water. Tolerance is ± 10% of full load data. 21. Heat rejection to atmosphere based on treated water. Tolerance is ± 50% of full load data. 22. Lube oil heat rate based on treated water. Tolerance is ± 20% of full load data. 23. Exhaust heat rate based on treated water. Tolerance is ± 10% of full load data. 24. Heat rejection to exhaust (LHV to 77ºF) value shown includes unburned fuel and is not intended to be used for sizing or recovery calculations. 25. Heat rejection to A/C - Stage 1 based on treated water. Tolerance is ±5% of full load data. 26. Heat rejection to A/C - Stage 2 based on treated water. Tolerance is ±5% of full load data. 27. Pump power includes engine driven jacket water and aftercooler water pumps. Engine brake power includes effects of pump power. 28. Total Jacket Water Circuit heat rejection is calculated as: (JW x 1.1) + (OC x 1.2) + (1AC x 1.05) + [0.85 x (1AC + 2AC) x (ACHRF - 1) x 1.05]. Heat exchanger sizing criterion is maximum circuit heat rejection at site conditions, with applied tolerances. A cooling system safety factor may be multiplied by the total circuit heat rejection to provide additional margin. 29. Total Second Stage Aftercooler Circuit heat rejection is calculated as: (2AC x 1.05) + [(1AC + 2AC) x 0.15 x (ACHRF - 1) x 1.05]. Heat exchanger sizing criterion is maximum circuit heat rejection at site conditions, with applied tolerances. A cooling system safety factor may be multiplied by the total circuit heat rejection to provide additional margin. Data generated by Gas Engine Data Master Version Ref. Data Set G , Printed 7/29/2015 Page 2 of 3

124 G3512 GAS ENGINE TECHNICAL DATA Load Step (%) Load Acceptance Initial Load (%) Max G1 G2 Transient Load Acceptance Load Step Frequency Deviation +/- Voltage Deviation +/- Recovery Time Classification as Defined by ISO % % sec / / / / / / / / G / / 20 6 G2 3 Breaker Open +25 / / Steady State Specification Recovery Specification / / / 5 +5 / 5 Notes Transient Information The transient load steps listed above are stated as a percentage of the engine s full rated load as indicated in the appropriate performance technical data sheet. Site ambient conditions, fuel quality, inlet/exhaust restriction and emissions settings will all affect engine response to load change. Engines that are not operating at the standard conditions stated in the technical data sheet should be set up according to the guidelines included in the technical data; applying timing changes and/or engine derates as needed. Adherence to the engine settings guidelines will allow the engines to retain the transient performance stated in the tables above as a percentage of the site derated power (where appropriate). Fuel supply pressure and stability is critical to transient performance. Proper installation requires that all fuel train components (including filters, shut off valves, and regulators) be sized to ensure adequate fuel be delivered to the engine. The following are fuel pressure requirements to be measured at the engine mounted fuel control valve. A. Steady State Fuel Pressure Stability +/ 6.9 mbar/sec (+/ 0.1 psi/sec) B. Transient fuel Pressure Stability +/ 48.2 mbar/sec (+/ 0.7 psi/sec) Inlet water temperature to the SCAC must be maintained at specified value for all engines. It is important that the external cooling system design is able to maintain the inlet water temp to the SCAC to within +/ 1 C during all engine operating cycles. The SCAC inlet temperature stability criterion is to maintain stable inlet manifold air temperature. The Air Fuel Ratio control system requires up to 180 seconds to converge after a load step has been performed for NOx to return to nominal setting. If the stabilization time is not met between load steps the transient performance listed in the document may not be met. Differences in generator inertia may change the transient response of engine. Engine Governor gains and Voltage regulator settings may need to be tuned for site conditions. Engines must be maintained in accordance to guidelines specified in the Caterpillar Service Manuals applicable to each engine. Wear of components outside of the specified tolerances will affect the transient capability of the engine. Data is representative of a properly warmed engine which is achieved when engine reaches nominal operating temperatures under steady state conditions. Notes 1 For unloading the engine to 0% load from a loaded condition no external input is needed. The engine control algorithm employs a load sensing strategy to determine a load drop to no load. In the event that the generator load drops to zero the strategy resets all control inputs to the rated idle condition. This prevents engine over speeding and will allow the engine to remain running unloaded at the rated synchronous speed. 2 The engine was tested against the voltage deviation, frequency deviation, and recovery time requirements defined in ISO At this time the engine will meet class G1 transient performance as defined by ISO with excpetions. 3 The engine was tested against the voltage deviation, frequency deviation, and recovery time requirements defined in ISO At this time the engine will meet class G2 transient performance as defined by ISO with excpetions. Data generated by Gas Engine Data Master Version Ref. Data Set G , Printed 7/29/2015 Page 3 of 3

125 Manufacturer Data to support Emission Factors for EQUIs 2 and 4 when temperatures are less than 0 F

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127 Solar Turbines Incorporated Product Information Letter 167 PIL 167 Product Information Letter SoLoNOx Products: Emissions in Non-SoLoNOx Modes Leslie Witherspoon Solar Turbines Incorporated PURPOSE Solar s gas turbine dry low NOx emissions combustion systems, known as SoLoNOx, have been developed to provide the lowest emissions possible during normal operating conditions. In order to optimize the performance of the turbine, the combustion and fuel systems are designed to reduce NOx, CO and unburned hydrocarbons (UHC) without penalizing stability or transient capabilities. At very low load and cold temperature extremes, the SoLoNOx system must be controlled differently in order to assure stable operation. The required adjustments to the turbine controls at these conditions cause emissions to increase. The purpose of this Product Information Letter is to provide emissions estimates, and in some cases warrantable emissions for NOx, CO and UHC, at off-design conditions. Historically, regulatory agencies have not required a specific emissions level to be met at low load or cold ambient operating conditions, but have asked what emissions levels are expected. The expected values are necessary to appropriately estimate emissions for annual emissions inventory purposes and for New Source Review applicability determinations, air dispersion modeling, and permitting. COLD AMBIENT EMISSIONS ESTIMATES Solar s standard temperature range warranty for gas turbines with SoLoNOx combustion is 0 F ( 20 C). The Titan 250 is an exception, with a lower standard warranty at 20 F ( 29 C). At ambient temperatures below 0 F, many of Solar s turbine engine models are controlled to increase pilot fuel which improves flame stability but leads to higher emissions. Without the increase in pilot fuel at temperatures below 0 F the engines may exhibit combustor rumble, as operation may be near the lean stability limit. If a cold ambient emissions warranty is requested, a new production turbine configured with the latest combustion hardware is required. For most models this refers to the inclusion of Cold Ambient Fuel Control Logic. A cold ambient emissions warranty is only available on gas turbines being fired on natural gas and not offered for ambient temperatures below 20 F ( 29 C). In general, standard natural gas as defined in ES9-98 is required to offer a cold ambient warranty, but non-standard fuels on a project basis can be reviewed by Solar to determine applicability. In addition, cold ambient emissions warranties cannot be offered for the Centaur 40 turbine. Note that a cold ambient warranty cannot be offered for liquid fuel operation at this time. Table 1 provides expected and warrantable (upon Solar s documented approval) emissions levels for Solar s SoLoNOx combustion turbines. All emissions levels are in ppm at 15% O2. Refer to Product Information Letter 205 for Mercury 50 turbine emissions estimates. For information on the availability and approvals for cold ambient temperature emissions warranties, please contact Solar s sales representatives. PIL 167 Revision March Solar Turbines Incorporated Caterpillar Confidential Green: Information contained herein is to be treated as Confidential and Proprietary to Caterpillar.

128 Solar Turbines Incorporated Product Information Letter 167 Table 1. Warrantable Emissions Between 0 F and 20 F ( 20 to 29 C) for New Production (NOx ppm values corrected to 15% O2.) Turbine Model Centaur 50 Fuel System Fuel Applicable Load NOx, ppm CO, ppm UHC, ppm Gas Only Gas 50 to 100% load Dual Fuel Gas 50 to 100% load Taurus 60 Gas Only or Dual Fuel Gas 50 to 100% load Taurus 65 Gas Only Gas 50 to 100% load Taurus 70 Gas Only or Dual Fuel Gas 50 to 100% load Mars 90 Gas Only Gas 50 to 100% load Mars 100 Gas Only or Dual Fuel Gas 50 to 100% load Titan 130 Gas Only or Dual Fuel Gas 50 to 100% load Titan 250 Gas Only Gas 40 to 100% load Gas Only Gas 40 to 100% load Table 2 summarizes expected emissions levels for ambient temperatures below 0 F ( 20 C) for Solar s SoLoNOx turbines that do not have current production hardware or for new production hardware that is not equipped with the Cold Ambient Fuel Control Logic. The emissions levels are extrapolated from San Diego factory tests and may vary at extreme temperatures and as a result of variations in other parameters, such as fuel composition, fuel quality, etc. For more conservative NOx emissions estimate on new equipment, customers can refer to the New Source Performance Standard (NSPS) 40CFR60, subpart KKKK, where the allowable NOx emissions level for ambient temperatures < 0 F ( 20 C) is 150 ppm NOx at 15% O2. For pre-february 18, 2005, SoLoNOx combustion turbines subject to 40CFR60 subpart GG, a conservative estimate is the appropriate subpart GG emissions level. Subpart GG levels range from 150 to 214 ppm NOx at 15% O2 on natural gas (and on liquid fuel) depending on the turbine model. Table 2. Expected Emissions below 0 F ( 20 C) for SoLoNOx Combustion Turbines (NOx ppm values corrected to 15% O2.) Turbine Model Fuel System Fuel Applicable Load NOx, ppm CO, ppm UHC, ppm Centaur 40 Gas Only or Dual Fuel Gas 80 to 100% load Centaur 50 Gas Only Gas 50 to 100% load Dual Fuel Gas 50 to 100% load Taurus 60 Gas Only or Dual Fuel Gas 50 to 100% load Taurus 65 Gas Only Gas 50 to 100% load Taurus 70 Gas Only or Dual Fuel Gas 50 to 100% load Mars 90 Gas Only Gas 80 to 100% load Mars 100 Gas Only or Dual Fuel Gas 50 to 100% load Titan 130 Gas Only or Dual Fuel Gas 50 to 100% load Centaur 40 Dual Fuel Liquid 80 to 100% load Centaur 50 Dual Fuel Liquid 65 to 100% load Taurus 60 Dual Fuel Liquid 65 to 100% load Taurus 70 Dual Fuel Liquid 65 to 100% load Mars 100 Dual Fuel Liquid 65 to 100% load Titan 130 Dual Fuel Liquid 65 to 100% load PIL 167 Revision March Solar Turbines Incorporated Caterpillar Confidential Green: Information contained herein is to be treated as Confidential and Proprietary to Caterpillar.

129 Manufacturer Data to support PM Emission Factors for Turbines, EQUIs 2 and 4

130 Solar Turbines Incorporated Product Information Letter 171 PIL 171 Product Information Letter Particulate Matter Emission Estimates Leslie Witherspoon Solar Turbines Incorporated PURPOSE This document summarizes Solar s recommended PM10/2.5 emission levels for our combustion turbines. The recommended levels are based on an analysis of emissions tests collected from customer sites. Particulate Matter Definition National Ambient Air Quality Standards (NAAQS) for particulate matter were first set in Total suspended particulate (TSP) was the first indicator used to represent suspended particles in the ambient air. Since July 1, 1987, the Environmental Protection Agency (EPA) has used the indicator PM10, which includes only the particles with aerodynamic diameter smaller than 10 micrometers (µm). PM10 (coarse particles) come from sources such as windblown dust from the desert or agricultural fields and dust kicked up on unpaved roads by vehicle traffic. The EPA added a PM2.5 ambient air standard in PM2.5 includes particles with an aerodynamic diameter less than 2.5 µm. PM2.5 (fine particles) are generally emitted from industrial and residential combustion and from vehicle exhaust. Fine particles are also formed in the atmosphere when gases such as sulfur dioxide, nitrogen oxides, and volatile organic compounds, emitted by combustion activities, are transformed by chemical reactions. Nearly all particulate matter from gas turbine exhaust is less than one micrometer (micron) in diameter. Thus the emission rates of TSP, PM10, and PM2.5 from gas turbines are theoretically equivalent although source testing will show variation due to test method detection levels and processes. TESTING FOR PARTICULATE MATTER The turbine combustion process has little effect on the particulate matter generated and measured. The largest contributor to particulate matter emissions for gas and liquid fired combustion turbines is measurement technique and error. Other, minor contributing, sources of particulate matter emissions include carbon, ash, fuel-bound sulfur, artifact sulfate formation, compressor/lubricating oils, and inlet air. Historical customer particulate matter source test data show that there is significant variability from test to test. The source test results support the common industry argument that particulate matter from natural gas fired combustion sources is difficult to measure accurately. The reference test methods for particulate matter were developed primarily for measuring emissions from coal-fired power plants and other major emitters of particulates. Particulate concentrations from gas turbine can be 100 to 10,000 times lower than the traditional particulate sources. The test methods were not developed or verified for low emission levels. There are interferences, insignificant at higher exhaust particulate matter concentrations that result in emissions greater than the actual emissions from gas turbines. New methods are being developed to address this problem. Due to measurement and procedural errors, the measured results, in most cases, may not be representative of actual particulate matter emitted. There are many potential error sources in measuring particulate matter. Most of these have to do with contamination of the samples, material from the sampling apparatus getting into the samples, and general human error in samples and analysis. Over the past few years, source test firms are gaining experience in measuring particulate matter and the variability that we ve seen historically from test to test and the emissions levels measured has decreased. 1 PIL 171 Revision 5 6 May 2015 Caterpillar Confidential Green: Information contained herein is to be treated as Confidential and Proprietary to Caterpillar Solar Turbines Incorporated

131 Solar Turbines Incorporated Product Information Letter 171 Recommended Particulate Matter Emission Factors When necessary to support the air permitting process Solar recommends the following PM10/2.5 emission factors: Pipeline Natural Gas*: lb/mmbtu fuel input (HHV) Landfill Gas : 0.03 lb/mmbtu fuel input (HHV) Liquid Fuel # : lb/mmbtu fuel input (HHV) * Pipeline natural gas emissions factor assumes <1 grains of Sulfur per 100 standard cubic feet. Landfill gas emissions factor assumes <0.15 lb SO2/MMBtu heat input. # Liquid fuel emission factor assumes fuel sulfur content is <500 ppm and ash content is <0.005% by wt. Contact Solar s Environmental Programs group for particulate matter emissions estimates for fuels not listed above. The conversion of a particulate matter emissions request from mg/nm 3 to lb/mmbtu (HHV) units involves several specific turbine parameters. Please contact Solar if you need the calculation performed. Recent customer source testing has shown that AP-42 (EPA AP-42 "Compilation of Air Pollutant Emission Factors. ) emission factors for natural gas are achievable in the field, when the test method recommendations shown below are followed. Historically, Solar did not recommend using AP-42 because while some source test firms have measured below AP-42 levels, others have measured higher. Because particulate matter emissions levels are highly dependent on the test firm and have very little to do with the turbine, Solar does not warrant AP-42 levels but does recognize they are achievable in the field. Customers generally choose a particulate matter emissions factor at or above the AP-42 level that works for their site permitting recognizing that the lower the emissions factor the higher the risk for source testing. Test Method Recommendation Solar recommends that EPA Methods 201/201A¹ be used to measure the front half. Front half represents filterable particulate matter. EPA Method 202² (with nitrogen purge and field blanks) should be used to measure the back half. Back half measurements represent the condensable portion of particulate matter. EPA Method 5³, which measures the front and back halves may be substituted (e.g. where exhaust temperatures do not allow the use of Method 202). The turbine should have a minimum of 300 operating hours prior to conducting particulate matter source testing. The turbine should be running for 3-4 hours prior to conducting a particulate matter source test so that the turbine and auxiliary equipment is in a sustained typical operating mode prior to gathering samples. Testing should include three 4-hour test runs. Solar recommends using the aforementioned test methods until more representative test methods are developed and widely commercially available. References ¹ EPA Method 201, Determination of PM10 Emissions, Exhaust Gas Recycle Procedure. EPA Method 201A, Determination of PM10 Emissions, Constant Sampling Rate Procedure, 40 CFR 60, Part 60, Appendix A. ² EPA Method 202, Determination of Condensible Particulate Emissions from Stationary Sources, 40 CFR 60, Part 60, Appendix A. ³ EPA Method 5, Determination of Particulate Emissions from Stationary Sources, 40 CFR 60, Part 60, Appendix A. Solar Turbines Incorporated 9330 Sky Park Court San Diego, CA Cat and Caterpillar are registered trademarks of Caterpillar Inc. Solar, Saturn, Centaur, Taurus, Mercury, Mars, Titan, SoLoNOx, Turbotronic, InSight System, and InSight Connect, are trademarks of Solar Turbines Incorporated. All other trademarks are the intellectual property of their respective companies Solar Turbines Incorporated. All rights reserved. Specifications are subject to change without notice. 2 PIL 171 Revision 5 6 May 2015 Caterpillar Confidential Green: Information contained herein is to be treated as Confidential and Proprietary to Caterpillar Solar Turbines Incorporated

132 Attachment 6. Performance testing report for EQUI 2

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