AIR QUALITY PERMIT. Kennesaw State University - Marietta Campus

Transcription

1 AIR QUALITY PERMIT Permit No. Effective Date February 11, 2016 In accordance with the provisions of the Georgia Air Quality Act, O.C.G.A. Section , et seq and the Rules, Chapter , adopted pursuant to and in effect under that Act, Facility Name: Kennesaw State University - Marietta Campus Mailing Address: 1200 Chastain Road, MD 0002, Bldg 200 Suite 201 Kennesaw, GA is issued a Permit for the following: Operation of a university campus including boilers and engines used for emergency generators. This Permit is issued for the purpose of establishing practically enforceable emission limitations such that the facility will not be considered a major source with respect to Title V of the Clean Air Act Amendments of Facility Location: 1100 South Marietta Parkway Marietta, Georgia (Cobb County) This Permit is conditioned upon compliance with all provisions of The Georgia Air Quality Act, O.C.G.A. Section , et seq, the Rules, Chapter , adopted and in effect under that Act, or any other condition of this Permit. This Permit may be subject to revocation, suspension, modification or amendment by the Director for cause including evidence of noncompliance with any of the above; or for any misrepresentation made in Application No dated June 5, 2015; any other applications upon which this Permit is based; supporting data entered therein or attached thereto; or any subsequent submittals or supporting data; or for any alterations affecting the emissions from this source. This Permit is further subject to and conditioned upon the terms, conditions, limitations, standards, or schedules contained in or specified on the attached 9 pages. [Signed] Director

2 Permit No. Page 1 of 9 1. General Requirements 1.1 At all times, including periods of startup, shutdown, and malfunction, the Permittee shall maintain and operate this source, including associated air pollution control equipment, in a manner consistent with good air pollution control practice for minimizing emissions. Determination of whether acceptable operating and maintenance procedures are being used will be based on information available to the Division which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection or surveillance of the source. 1.2 The Permittee shall not 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 emission standard. Such concealment includes, but is not limited to, the use of gaseous diluents to achieve compliance with an opacity standard or with a standard that is based on the concentration of a pollutant in the gases discharged into the atmosphere. 1.3 The Permittee shall submit a Georgia Air Quality Permit application to the Division prior to the commencement of any modification, as defined in (pp), which may result in air pollution and which is not exempt under (6). Such application shall be submitted sufficiently in advance of any critical date involved to allow adequate time for review, discussion, or revision of plans, if necessary. The application shall include, but not be limited to, information describing the precise nature of the change, modifications to any emission control system, production capacity and pollutant emission rates of the plant before and after the change, and the anticipated completion date of the change. 1.4 Unless otherwise specified, all records required to be maintained by this Permit shall be recorded in a permanent form suitable for inspection and submission to the Division and shall be retained for at least five (5) years following the date of entry. 1.5 In cases where conditions of this Permit conflict with each other for any particular source or operation, the most stringent condition shall prevail. 1.6 Conditions 2.1, 2.4, 2.5, 2.6, 2.7, 2.9, 2.10, 2.12, 4.2, 5.5, 7.3, and 7.5 shall be in effect upon the installation of subject equipment.

3 Permit No. Page 2 of 9 2. Allowable Emissions Boilers 2.1 The Permittee shall comply with all applicable provisions of the New Source Performance Standards (NSPS) as found in 40 CFR 60 Subpart A "General Provisions" and 40 CFR 60 Subpart Dc - "Standards of Performance for Small Industrial-Commercial-Institutional Steam Generating Units," for operation of boilers subject to 40 CFR 60 Subpart Dc (hereafter Dc Boiler ). [40 CFR 60 Subparts A and Dc] 2.2 The Permittee shall not cause, let, suffer, permit, or allow any emissions from the following which: a. Contain fly ash and/or other particulate matter in amounts equal to or exceeding the rate derived from P = 0.5(10/R) 0.5 where R equals heat input rate in million BTU per hour and P equals the allowable emission rate in pounds per million BTU from any boiler. [ (2)(d)2.(ii)] b. Exhibit visible emissions, the opacity of which is equal to or greater than 20 percent except for one six minute period per hour of not more than 27 percent opacity from any boiler. [ (2)(d)3.] 2.3 The Permittee shall only fire natural gas and fuel oil in the facility s boilers. In particular, fuel oil shall only be burned during periods of gas curtailment, gas supply emergencies, or periods of testing on fuel oil. Testing on fuel oil shall not exceed 48 hours per calendar year. [Avoidance of 40 CFR 63 Subpart JJJJJJ ] 2.4 The permittee shall only fire distillate oil in Dc Boilers. The distillate oil shall not contain more than 0.5 percent sulfur by weight. Distillate fuel oil means fuel oil that complies with the specifications for fuel oil number 1 or 2, as defined by the American Society for Testing and Materials (ASTM) standard ASTM D396, Standard Specification for Fuel Oils. [40 CFR 60.42c(d)]

4 Permit No. Page 3 of 9 Generators 2.5 The Permittee shall comply with all applicable provisions of 40 CFR 60 New Source Performance Standards (NSPS), Subpart A - "General Provisions" and Subpart IIII Standards for Stationary Compression Ignition Internal Combustion Engines, for the operation of Emergency Generators subject to 40 CFR 60 Subpart IIII (hereafter Subpart IIII Engines ). The Permittee shall comply with emission standards for hydrocarbons (HC), NOx, carbon monoxide (CO), and PM as listed in Table 1 of Subpart IIII during the useful life of the engine. [40 CFR (a) and 40 CFR ] 2.6 The Permittee shall comply with all applicable provisions of 40 CFR 60 New Source Performance Standards (NSPS), Subpart A - "General Provisions" and Subpart JJJJ Standards for Stationary Spark Ignition Internal Combustion Engines, for the operation of Emergency Generators subject to 40 CFR 60 Subpart JJJJ (hereafter Subpart JJJJ Engines ). [40 CFR 60 Subpart JJJJ] 2.7 The Permittee shall comply with all applicable provisions of the National Emission Standards for Hazardous Air Pollutants (NESHAP) Subpart ZZZZ National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines and the applicable provisions of Subpart A, "General Provisions" as defined in Table 8 of 40 CFR 63 Subpart ZZZZ for operation of all emergency generators. Engines that are subject to Subpart ZZZZ shall demonstrate compliance by demonstrating compliance with the appropriate 40 CFR 60 New Source Performance Standard (NSPS). Existing engines at the facility are exempt from the requirements of Subpart ZZZZ under 40 CFR (f)(3). [40 CFR and Table 8 of 40 CFR 63 Subpart ZZZZ] 2.8 The Permittee shall limit the total operation of Emergency Generators not to exceed 200 hours of operation per generator during any twelve consecutive months including both emergency service and non-emergency service (maintenance and testing). Any operation other than emergency operation, maintenance check and readiness testing is prohibited. [ (2)(c) and Title V Avoidance] 2.9 The accumulated non-emergency service (maintenance check and readiness testing) time for each of the Subpart IIII Engines shall not exceed 100 hours per year. Any operation other than emergency operation, maintenance check and readiness testing is prohibited. [40 CFR (e)] 2.10 The Permittee shall not discharge into or cause the discharge into the atmosphere from each of the Subpart IIII Engines any visible emissions the opacity of which is equal to or greater than 20 percent during the acceleration mode, 15 percent during the lugging mode; and 40 percent during the peaks in either the acceleration or lugging modes. [40 CFR (b), 40 CFR (a)(2) and 40 CFR ]

5 Permit No. Page 4 of The Permittee shall not cause, let suffer, permit, or allow emissions from Emergency Generators or any other stack, the opacity of which is equal to or greater than 40 percent. [ (2)(b)] 2.12 The Permittee shall purchase and use diesel fuel that has a maximum sulfur content of 15 ppm (0.0015% by weight) and either a minimum cetane index of 40 or maximum aromatic content of 35 volume percent in the Subpart IIII Engines. [40 CFR and 40 CFR (b)] Campus-wide 2.13 The Permittee shall not discharge or cause the discharge into the atmosphere from the entire campus NOx emissions greater than 24.5 tons during any 12-consecutive month period [Title V Avoidance] 2.14 The Permittee shall not burn fuel containing more than 2.5 percent sulfur, by weight, in any fuel-burning source, that has a heat input capacity below 100 million Btu per hour. [ (2)(g)] 3. Fugitive Emissions 3.1 The Permittee shall take all reasonable precautions with any operation, process, handling, transportation, or storage facilities to prevent fugitive emissions of air contaminants. 4. Process & Control Equipment 4.1 Routine maintenance shall be performed on all air pollution control equipment. Maintenance records shall be recorded in a permanent form suitable and available for inspection by the Division. The records shall be retained for at least five (5) years following the date of such maintenance. 4.2 All Subpart IIII Engines shall be operated and maintained according to the manufacturer s written specifications/instructions or procedures developed by the Permittee that are approved by the engine manufacturer, over the entire life of each engine. [40 CFR (a)]

6 Permit No. Page 5 of 9 5. Monitoring 5.1 Any monitoring system or device installed by the Permittee shall be in continuous operation except during calibration check, zero, and span adjustments or periods of repair. Maintenance or repair shall be conducted in the most expedient manner to minimize the period during which the system or device is out-of-service. 5.2 The Permittee shall install, calibrate, operate and maintain a cumulating hour meter on each emergency generator. 5.3 The Permittee shall install, calibrate and maintain fuel consumption meters for the facility to monitor fuel oil and natural gas consumption in the boilers. 5.4 The Permittee shall verify that each shipment of distillate fuel oil received for combustion in any emission unit, listed in the facility description, is distillate oil, No. 2 fuel oil, No. 2 diesel fuel oil or very low sulfur diesel fuel oil and that the oil complies with the requirements of Conditions 2.4, 2.12, and Verification shall consist of either of the following: a. Fuel oil receipts obtained from the fuel supplier certifying that the oil is distillate oil, No. 2 fuel oil, No. 2 diesel fuel oil or very low sulfur diesel fuel oil. Fuel supplier certification shall include the following information; (1) the name of the oil supplier and, (2) a statement from the oil supplier that the oil complies with the specifications under the definition of distillate fuel oil or b. Analysis of the fuel oil conducted by methods sampling and analysis, which have been specified or approved by the Division. 5.5 The Permittee shall install, calibrate, maintain, and operate a non-resettable continuous monitoring system (or device) for Subpart IIII Engines to monitor and record the hours operated during emergency service, to monitor and record the hours of operation in nonemergency service (maintenance and/or testing), and to monitor and record the cumulative total hours of operation. Each system shall meet the applicable performance specification(s) of the Division s monitoring requirements. [40 CFR (a)]

7 Permit No. Page 6 of 9 6. Performance Testing 6.1 The Permittee shall cause to be conducted a performance test at any specified emission point when so directed by the Division. The following provisions shall apply with regard to such tests: a. All tests shall be conducted and data reduced in accordance with applicable procedures and methods specified in the Division s Procedures for Testing and Monitoring Sources of Air Pollutants. b. All test results shall be submitted to the Division within sixty (60) days of the completion of testing. c. The Permittee shall provide the Division thirty (30) days prior written notice of the date of any performance test(s) to afford the Division the opportunity to witness and/or audit the test, and shall provide with the notification a test plan in accordance with Division guidelines. d. All monitoring systems and/or monitoring devices required by the Division shall be installed, calibrated and operational prior to conducting any performance test(s). For any performance test, the Permittee shall, using the monitoring systems and/or monitoring devices, acquire data during each performance test run. All monitoring system and/or monitoring device data acquired during the performance testing shall be submitted with the performance test results. 7. Notification, Reporting and Record Keeping Requirements 7.1 The Permittee shall retain monthly records of all fuel burned at the Facility for five years after the date and year of record. The records shall be available for inspection or submittal to the division, upon request, and contain the following: a. Fuel supplier certifications or fuel oil analyses required by Condition 5.4. b. Quantity of distillate fuel oil burned in boilers. c. The total campus-wide quantity of natural gas burned.

8 Permit No. Page 7 of Monthly NO x emissions from fuel combustion shall be determined by the following equation: NO x lb scf 2000 m n lb 0.02 lb 0.024lb 0.031lb ton ( V ) + ( V ) + ( V ) + ( HP )( t ) + ( HP )( t ) = NG NGen FO L L scf gal S S L= 1 S= 1 lb hp hr hp hr Where, NO x = Total NO x emissions, in tons, during the calendar month. V NG = Total volume of natural gas, in standard cubic feet (scf), consumed campus-wide in external combustion sources during the calendar month. V NGen = Total volume of natural gas, in standard cubic feet (scf), consumed campus-wide in internal stationary combustion sources during the calendar month V FO = Total volume of fuel oil, in gallons (gal), consumed by all during the calendar month. HP = Rated horsepower (hp) of each engine. t = Total time of operation, in hours (hr), for each engine during the calendar month. L = Counter for the large generators. For the purposes of this calculation, the large generators are those with a rated horsepower of greater than 600 BHP. S = Counter for the small generators. For the purposes of this calculation, the small generators are those with a rated horsepower of 600 BHP or less. m = Total number of large generators. n = Total number of small generators. 7.3 The Permittee shall keep records verifying that each shipment of diesel fuel received for firing in Subpart IIII Engines complies with the applicable requirements in Condition Verification shall consist of either the fuel oil receipts and/or fuel supplier certifications or results of analyses of the fuel oils conducted by methods of sampling and analysis which have been specified or approved by the EPA or the Division. 7.4 The Permittee shall maintain monthly operating records of each of the emergency generators, including operating hours and reasons of the operation, i.e., emergency power generation, readiness testing and/or maintenance check.

9 Permit No. Page 8 of The Permittee shall demonstrate compliance with the applicable emission limits in Condition 2.5 according to one of the following methods: a. Purchasing engines certified according to 40 CFR Part 89, for the same model year and maximum engine power. The engine shall be installed and configured according to the manufacturer s specifications; b. Keeping records of performance test results for each pollutant for a test conducted on a similar engine. The test shall have been conducted using the same methods specified in 40 CFR 60, Subpart IIII and those methods shall have been followed correctly; c. Keeping records of engine manufacturer data indicating compliance with the standards; Records shall be maintained for a period of five (5) years in a format suitable for inspection by or submission to the Division. 7.6 The Permittee shall submit a semiannual report by July 30 of the calendar year of record and by January 30 of the year following the calendar year of record unless otherwise approved by the Division. The report shall be prepared from records retained in accordance with Conditions 7.1 through 7.5, submitted in a manner suitable to the Division and containing the following: a. A statement, signed by an official of the company, affirming that all fuel oil, diesel fuel or low sulfur diesel fuel oil burned during the reporting period met the specifications, as required by Conditions 2.4, 2.12, and b. The total operating hours for each emergency engine driven generators (per condition 2.8) during each of the previous twelve consecutive month periods for each calendar month in the semiannual reporting period (i.e. six 12 month totals). c. The twelve-month total quantities of campus-wide natural gas use for each calendar month in the semiannual reporting period. d. The total 12-consecutive month campus-wide NOx emissions for each month in the semiannual period. 7.7 The Permittee shall keep a written record of each and all instances during which fuel oil was fired in a boiler. The record shall be available for submittal to and review by the Division and contain the date and time, duration of event, and the reason fuel oil was fired. [Avoidance of 40 CFR 63 Subpart JJJJJJ ]

10 Permit No. Page 9 of 9 8. Special Conditions 8.1 At any time that the Division determines that additional control of emissions from the facility may reasonably be needed to provide for the continued protection of public health, safety and welfare, the Division reserves the right to amend the provisions of this Permit pursuant to the Division's authority as established in the Georgia Air Quality Act and the rules adopted pursuant to that Act. 8.2 The Permittee shall calculate and pay an annual Permit fee to the Division. The amount of the fee shall be determined each year in accordance with the Procedures for Calculating Air Permit Fees. 8.3 The Permittee may construct and operate additional fuel combustion equipment, provided the following requirements are met: a. The additional fuel combustion equipment is included in any applicable recordkeeping requirements including hours of operation for emergency generators per Condition 7.4, campus-wide fuel usage per Conditions 7.1, and monthly NOx emission records per Condition 7.2. b. The additional fuel combustion equipment is included in any applicable monitoring requirements per Condition 5.2. c. The additional fuel combustion equipment is included in any applicable reporting requirements per Condition 7.5 and 7.6 d. Additional emergency generators are subject to the limitations of Conditions 2.5 through e. The additional fuel combustion equipment is exempt from the requirement to obtain an Air Quality Permit in accordance with (6)(b).