62-296.405. Existing Fossil Fuel Steam Generators with Greater than or Equal to 250 Million Btu Per Hour Heat Input

(1) Applicability. Rule 62-296.405, F.A.C., applies to existing fossil fuel steam generators with greater than or equal to 250 MMBtu per hour heat input. For the purposes of this rule, “existing” means the emission unit was in existence, in operation, or under construction, or had received a permit to begin construction prior to January 18, 1972.

(2) Visible emissions – 20 percent opacity except for one six-minute period per one-hour period during which opacity shall not exceed 27 percent. Emissions units governed by this visible emissions limit shall test for particulate emissions annually and as otherwise required by Chapter 62-297, F.A.C. Emissions units electing to test for particulate matter emissions quarterly or emissions units equipped with a continuous emissions monitoring system for particulate matter that meets the requirements of paragraph 62-296.405(4)(b), F.A.C., shall be allowed visible emissions of 40 percent opacity. The results of such tests shall be submitted to the Department or local program, as specified in the facility’s permit. Upon demonstration that the particulate standard has been regularly complied with, the Secretary, upon petition by the applicant, shall reduce the frequency of particulate testing to no less than once annually.

(3) Particulate Matter – 0.1 pound per million Btu heat input, as measured by stack test. If compliance is demonstrated with a particulate matter continuous emission monitoring system, then compliance shall be determined on a heat-input weighted 30-operating day rolling average basis, including all periods of operation. Compliance is determined by first summing the total pounds of the pollutant in question emitted from the Unit during an operating day and the previous 29 operating days; second, sum the total heat-input to the Unit in MMBtu during the operating day and the previous 29 operating days; and third, divide the total number of pounds of the pollutant emitted during the 30 operating days by the total heat input during the 30 operating days. An operating day is defined as any day (midnight to midnight) when fuel is fired.

(4) Sulfur Dioxide, as measured by fuel sampling. If compliance is demonstrated with a sulfur dioxide continuous emission monitoring system, then compliance shall be determined on a 24-hour block average, including all periods of operation, unless a different averaging period is specified below. Compliance is determined by calculating the arithmetic average of all valid hourly averages occuring within that day.

(a) Emissions units burning liquid fuel.

1. Emissions units in Duval County with a nameplate generating capacity of greater than 250 MW which commenced operation prior to August 1, 1977 – 1.98 pounds per million Btu heat input.

2. Emissions units in Duval County with a nameplate generating capacity of less than 160 MW which commenced operation prior to October 1, 1964 – 1.10 pounds per million Btu heat input.

3. All other emissions units in Duval County – 1.65 pounds per million Btu heat input.

4. Hillsborough County, emissions units south of State Highway 60 with a nameplate generating capacity of less than 100 MW which commenced operation prior to June 1, 1955 – 1.1 pounds per million Btu heat input.

5. Escambia County, emissions units north of Interstate 10 with a nameplate generating capacity of less than 50 MW which commenced operation prior to October 1, 1952 – 1.98 pounds per million Btu heat input.

6. Escambia County, no emissions unit north of Interstate 10 with a rated heat input of 515 million Btu per hour or less for which a valid Department operating permit was issued prior to September 30, 1972 shall emit in the aggregate more than 57.5 tons per any 24 hour period.

7. Manatee County, emissions units with a nameplate generating capacity of greater than 700 MW for which a valid Department operating permit was issued prior to January 1, 1979 – 1.1 pounds per million Btu heat input.

8. Leon and Wakulla Counties, emissions units with a nameplate generating capacity of less than 260 MW for which a valid Department operating permit was issued prior to November 1, 1977 – 1.87 pounds per million Btu heat input.

9. Dade, Broward, and Palm Beach Counties, emissions units with a nameplate generating capacity of less than 170 MW which commenced operation prior to May 1, 1958 – 1.1 pounds per million Btu heat input, except in the event of a fuel or energy crisis declared by the Governor of Florida or the President of the United States – 2.75 pounds per million Btu heat input. Notification concerning the quantity and estimated duration of the increase in emissions shall be given to the Department prior to burning the higher sulfur fuel.

10. All other areas of the State – 2.75 pounds per million Btu heat input.

(b) Emissions units burning solid fuel.

1. Hillsborough County, no emissions unit with a nameplate generating capacity of greater than 120 MW which commenced operation prior to November 1, 1967, shall emit more than 2.4 pounds of sulfur dioxide per million Btu heat input on a weekly average nor shall a group of such emissions units located on one or more contiguous or adjacent properties and which are under common control emit more than 10.6 tons per hour of sulfur dioxide on a weekly average. A plan for assuring compliance with Florida Ambient Air Quality Standards will be incorporated into the revised operating permit for such emissions units.

2. Hillsborough County, no emissions unit with a nameplate generating capacity of greater than 400 MW which commenced operation after November 1, 1967, and prior to June 1, 1976, shall emit in total more than 6.5 pounds of sulfur dioxide per million Btu heat input on a two hour average nor shall a group of such emissions units located on one or more contiguous or adjacent properties and which are under common control emit more than 31.5 tons per hour of sulfur dioxide on a three hour average and 25 tons per hour of sulfur dioxide on a 24 hour average.

3. Escambia County, emissions units north of Interstate 10 with a nameplate generating capacity of more than 50 MW which commenced operation prior to September 1, 1973 – 5.90 pounds per million Btu heat input.

4. All other areas of the State – 6.17 pounds per million Btu heat input.

(5) Nitrogen Oxides (expressed as NO2) – as measured by stack test. If compliance is demonstrated with a nitrogen oxides continuous emission monitoring system, then compliance shall be based on a heat-input weighted 30-operating day rolling average basis, including all periods of operation. Compliance is determined by first summing the total pounds of the pollutant in question emitted from the Unit during an operating day and the previous 29 operating days; second, sum the total heat-input to the Unit in MMBtu during the operating day and the previous 29 operating days; and third, divide the total number of pounds of the pollutant emitted during the 30 operating days by the total heat input during the 30 operating days. An operating day is defined as any day (midnight to midnight) when fuel is fired.

(a) Duval County, emissions units with a nameplate generating capacity of greater than 450 MW which commenced operation prior to August 1, 1977 – 0.30 pounds per million Btu heat input.

(b) Manatee County, emissions units with a nameplate generating capacity of greater than 700 MW for which a valid Department operating permit was issued prior to January 1, 1979 – 0.30 pounds per million Btu heat input.

(c) Leon County, emissions units with a nameplate generating capacity of greater than 200 MW for which a valid Department operating permit was issued prior to November 1, 1977 – 0.30 pounds per million Btu heat input.

(d) Hillsborough County, emissions units with a nameplate generating capacity of greater than 400 MW which commenced operation after January 1, 1976 and prior to January 1, 1985 – 0.70 pounds per million Btu heat input.

(6) Test Methods and Procedures. All emissions tests performed pursuant to the requirements of this rule shall comply with the following requirements.

(a) The test method for visible emissions shall be EPA Method 9, described at 40 C.F.R. Part 60, Appendix A-4, adopted and incorporated by reference at Rule 62-204.800, F.A.C. In lieu of Method 9 testing, a transmissometer utilizing a six-minute block average for opacity measurement may be used, provided such transmissometer is installed, certified, calibrated, operated and maintained in accordance with the provisions of 40 C.F.R. Part 75, adopted and incorporated by reference at Rule 62-204.800, F.A.C.

(b) The test methods for particulate emissions shall be EPA Methods 17, 5, 5B, or 5F. The minimum sample volume shall be 30 dry standard cubic feet. EPA Method 5 may be used with filter temperature at no more than 320 degrees Fahrenheit. For EPA Method 17, stack temperature shall be less than 375 degrees Fahrenheit. EPA Method 3 or 3A with Orsat analysis shall be used when the oxygen base F-factor computed according to EPA Method 19 is used in lieu of heat input. Acetone wash shall be used with EPA Method 5 or 17. Methods 3 and 3A are described at 40 C.F.R. Part 60, Appendix A-2; EPA Methods 5, 5B, and 5F are described at 40 C.F.R. Part 60, Appendix A-3; EPA Method 17 is described at 40 C.F.R. Part 60, Appendix A-6; and EPA Method 19 is described at 40 C.F.R. Part 60, Appendix A-7; adopted and incorporated by reference at Rule 62-204.800, F.A.C. In lieu of EPA Method 17, 5, 5B, or 5F, an emissions unit may demonstrate compliance using a particulate matter continuous emissions monitoring system that meet the requirements of Performance Specification 11, adopted and incorporated by reference in Rule 62-204.800, F.A.C.

(c) The test methods for sulfur dioxide emissions shall be EPA Methods 6, 6A, 6B or 6C, as described at 40 C.F.R. Part 60, Appendix A-4, adopted and incorporated by reference at Rule 62-204.800, F.A.C. Fuel sampling and analysis may be used as an alternate sampling procedure if such a procedure was incorporated in the operation permit for the emissions unit prior to April 23, 1985. Otherwise, fuel sampling and analysis may be used if the emissions unit obtains an alternate procedure under the provisions of Rule 62-297.620, F.A.C. Such alternate procedure shall become a condition of the emissions unit's permit. The Department will retain the authority to require EPA Method 6 or 6C if it has reason to believe that exceedances of the sulfur dioxide emissions limiting standard are occurring. Results of an approved fuel sampling and analysis program or continuous emissions monitoring program shall have the same effect as EPA Method 6 test results for purposes of demonstrating compliance or noncompliance with sulfur dioxide standards.

(d) The test method for nitrogen oxides shall be a nitrogen oxides continuous emissions monitor meeting the requirements of 40 C.F.R. Part 75, as adopted and incorporated by reference in Rule 62-204.800, F.A.C.

(e) Test procedures shall meet all applicable requirements of Chapter 62-297, F.A.C.

(7) Continuous Emissions Monitoring Requirements. Each owner or operator of an emissions unit subject to Rule 62-296.405, F.A.C., shall install, calibrate, operate and maintain a continuous monitoring system for continuously monitoring the pollutants specified in this subsection. Performance specifications, location of monitor, data requirements, data reduction and reporting requirements shall conform with the requirements of 40 C.F.R. Part 51, Appendix P, and 40 C.F.R. Part 60, Appendix B, adopted and incorporated by reference in Rule 62-204.800, F.A.C., for existing and new emissions units provided, however, any alternative procedure (as specified in Section 3.9, 40 C.F.R. Part 51, Appendix P) or special consideration (as specified in Section 6.0, 40 C.F.R. Part 51, Appendix P) shall be incorporated in the Department’s air permit for the emissions unit and submitted to the U.S. Environmental Protection Agency as a proposed revision to the State Implementation Plan.

(a) Existing fossil fuel steam generators with more than 250 million BTU per hour heat input and with a capacity factor of greater than 30 percent for the latest year of record or as otherwise documented to the Department by the owner or operator, shall install continuous monitoring systems as set forth in this subparagraph. Any reactivated or previously exempted unit whose operated capacity factor for the previous six months is greater than 30 percent must install continuous monitoring systems as set forth in this subparagraph no later than twelve months following the previous six month period of achieving a capacity factor greater than 30 percent.

1. Opacity. All emissions units as set forth in paragraph 62-296.405(7)(a), F.A.C., shall install continuous monitoring systems for monitoring opacity. Exempted are:

a. Emissions units burning only gas, oil, or gas and oil which comply with the applicable state visible emission limiting standard without the use of emission control equipment.

b. Any emissions unit using a wet scrubber.

2. Sulfur dioxide. All emissions units as set forth in paragraph 62-296.405(7)(a), F.A.C., shall install sulfur dioxide continuous monitoring equipment on units which have installed sulfur dioxide control equipment. Those emissions units not having an operating flue gas desulfurization device may monitor sulfur dioxide emissions by fuel sampling and analysis according to methods approved by EPA.

3. Nitrogen Oxides. All new emissions units as set forth in paragraph 62-296.405(7)(a), F.A.C., with more than 1000 million BTU per hour heat input shall, during construction, install continuous monitoring systems for monitoring nitrogen oxides.

4. Oxygen or Carbon Dioxide. A continuous monitoring system shall be installed at each emissions unit, as set forth in paragraph 62-296.405(7)(a), F.A.C., where measurements of oxygen or carbon dioxide in the flue gas are utilized to convert either sulfur dioxide or nitrogen oxides continuous emission monitoring data to units of the emission limiting standards for proof of compliance as set forth in Rule 62-296.405, F.A.C.

(b) The exemption from opacity monitoring under sub-subparagraph 62-296.405(7)(a)1.a., F.A.C., shall not apply to any emissions unit which has been found to be in violation of the visible emission limiting standard pursuant to administrative proceedings conducted under Chapter 120, F.S., or judicial proceedings after January 1, 1978. No later than ninety days following the date an order establishing such violation becomes final, the owner or operator of such emissions unit shall submit to the Department a proposed compliance schedule for installing a continuous opacity monitoring system. Following incorporation of a compliance schedule into the emission unit's air permit, the owner or operator shall install the continuous monitoring system in accordance with the schedule.

(8) Semi-annual Reporting Requirements. The owners or operators of facilities for which monitoring is required shall submit to the Department a written report of emissions in excess of emission limiting standards as set forth in Rule 62-296.405, F.A.C., for each semi-annual period. Each semi-annual report shall cover the 6-month periods of January 1 – June 30 and July 1 – December 31. The reports shall be submitted by the 60th day following the end of each calendar half (i.e., March 1st and August 29th of every year). The nature and cause of the excessive emissions shall be explained. This report does not relieve the owner or operator of the legal liability for violations. All recorded data shall be maintained on file by the Source for a period of two years.

(9) For the purposes of this rule, nameplate generating capacity means the manufacturer's capacity rating of electrical generating output (expressed in MWe) as designed.

Rulemaking Authority 403.061 FS. Law Implemented 403.031, 403.061, 403.087 FS. History–Formerly 17-2.600(5), Amended 6-29-93, Formerly 17-296.405, Amended 11-23-94, 1-1-96, 3-13-96, 3-2-99, 7-10-14, 6-23-22.