Findings Of Fact This cause comes on for consideration based upon the petition of John C. Walker and others, residents of Fort Myers, Florida, who have challenged the Respondent, State of Florida, Department of Environmental Regulation's intention to grant a Complex Air Source Permit to the Respondent, Lee County Board of County Commissioners, for purposes of constructing a four-lane road at Daniels Road, Lee County, Florida. The Respondent, State of Florida, Department of Environmental Regulation, is an agency charged with the promotion and protection of air quality within the State of Florida. The authority for this function is found in Chapter 403, Florida Statutes, and various rules enacted to implement the provisions of this statute. Specifically, as it pertains to this dispute, the Respondent, State of Florida, Department of Environmental Regulation, is charged with the maintenance of Ambient Air Quality Standards. The standards are set forth in Chapter 17-2, Florida Administrative Code. To carry out this function, Rule 17-2.06, Florida Administrative Code, has been enacted, which establishes maximum limiting levels for Ambient Air Quality Standards. This sets the allowable limits for pollutants existing in the ambient air, the purpose for such standards being the protection of human health and public welfare. It involves the consideration of the pollutants, sulphur dioxide, particulate matter, carbon monoxide, photochemical oxidants (by measurement and correction for interference due to nitrogen oxide and sulphur dioxide), hydrocarbons (used as a guide in devising implementation plans to achieve oxidant standards, to be measured and corrected to methane), and nitrogen dioxide. The Respondent, Lee County Board of County Commissioners, is a unit of local government in the State of Florida charged with the function of carrying on the business of government for that county, to include the construction of those roads necessary to accommodate the needs of the public. To that end, on February 1, 1978, the Respondent, Lee County Board of County Commissioners, applied for a Complex Air Source Permit to be granted for the construction of a four-lane road at Daniels Road, Lee County, Florida. Subsequent to that initial application, revisions of the data provided in support of the application were made on October 12, 1978, and again on January 19, 1979. That application, as revised, may be found as the Respondent's (Lee County) Exhibit No. 1 admitted into evidence and includes aerial photographs. On May 4, 1978, through the person of Phillip R. Edwards, District Manager of the State of Florida, Department of Environmental Regulation, South Florida District, an indication was given that the department intended to issue a Complex Air Source Permit to the Lee County Board of County Commissioners. This exhibit is found as the Respondent's (Lee County) Exhibit No. 2 admitted into evidence. An engineer for the South Florida District, State of Florida, Department of Environmental Regulation, has made a review of the revisions in addition to the original application and is still of the persuasion that the Complex Air Source Permit should be granted. This letter of intent to grant the permit makes reference to the permitting chapter of the Florida Administrative Code pertaining to Complex Air Source Permits and other types of permits. Rule 17-4.07, Florida Administrative Code, sets out the general criterion which must be met prior to the issuance of the Complex Air Source Permit. That provision establishes the need for the applicant to affirmatively provide reasonable assurances based on its plans, test results and other information that the construction of the road and operation on that road will not discharge, emit or cause a violation of the Ambient Air Quality Standards set forth in Rule 17-2.06, Florida Administrative Code, previously referenced. In this case, those assurances have been given. In examining the particular pollutants set out in the Ambient Air Quality Standards table, sulphur dioxide and particulate matter are not items of significant concern, because motor vehicles do not promote the emission of those pollutants in quantities sufficient to exceed the maximum limiting levels. In measuring the amount of carbon monoxide, Lee County utilized a technique known as the representative site method, to be applied in the Cal-Air Model. The ecolyzer which measures this pollutant, was placed in various locations near the intersection of U.S. 41 and Daniels Road, with the object in mind to achieve the gravest readings as a basis for projecting the future amounts of carbon monoxide that would be present in the area of the proposed road expansion. The traffic projections and average speed at the intersection were factored in by Joseph Ebner, P.E., an expert in traffic engineering. The most recent statement of those traffic projections may be found in the January 19, 1979, revision to the application offered by the Respondent, Lee County Board of County Commissioners, which is a part of that Respondent's Exhibit No. 1. In that revision, as was the case of the revision of October 12, 1978, and the original application, the average speed at the intersection was established at fifteen miles per hour, calculated from an engineering textbook, "Highway Capacity Handbook (1975), Highway Research Board, Special Report No. 87". This represents the lowest average speed for an eight-hour period in a signalized intersection of an urban area. In arriving at the traffic count calculations, Mr. Ebner relied on the Lee County Transportation Study, Technical Report No. 6, which contains traffic projections for the year 1990. A copy of this report may be found as Petitioner's Exhibit No. 10 admitted into evidence. The statistics found in that report take into account the projected construction of a regional airport located east of Interstate-75 on Daniels Road, to be opened in the year 1982, and the Opinion that Canal Road, which will intersect with Daniels Road, will be opened in that same year. Calculations made in the January 1, 1979, revision are based upon the belief of a rate of increase in traffic to be eight percent per annum in the area of the intersection of U.S. 41, Cypress Lake Drive and Daniels Road. (At this point it should be indicated that the calculations in the revision of January 1, 1979, labeled, 8-hour Co. Concentrations, U.S. 41 & Cypress Lake Drive [natural traffic mix], are improperly depicted in the columns entitled, "U.S. 41 and Cypress Lake Drive" and must be transposed in their labeling to arrive at the proper mathematical result.) When that adjustment is made, it is established that the highest concentration of carbon monoxide in an eight-hour period in the intersection of U.S. 41 and Cypress Lake Drive in the location of the northwest quadrant for the years 1980 through 1990 was in the year 1980. In that year the measurement would be 9.13 mg/m3 in an eight-hour period. The second most severe year is 1981, in which the measurement is 9.10 mg/m3 as the highest eight-hour carbon monoxide concentration levels in that intersection. The balance of those measurements for the years 1982 through 1990 may be found in the Respondent's, Lee County Board of County Commissioners, Exhibit No. 1 in the January 19, 1979, revision to the permit application. Finally, it should be indicated that the projections made by the Lee County Board of County Commissioners in its application are premised upon a vehicular mix of ninety-four percent automobiles and six percent trucks. Tom Davis, an engineer for the Department of Environmental Regulation, who has the responsibility to review permit applications for Complex Air Source Permits, was involved in advising the applicant on the requirements for compliance for the granting of the permit. Through his involvement, Mr. Davis has been satisfied with the techniques used by the applicant in its efforts at measuring the carbon monoxide and the modeling necessary to answer the ultimate question of whether or not this project will violate the Ambient Air Quality Standards. In this instance, Mr. Davis does not believe those air quality standards will be violated. His testimony established that there are no models designed specifically for the measurement of photochemical oxidants, hydrocarbons or nitrogen dioxide. The hydrocarbons and nitrogen dioxide are area wide phenomena and are not subject to such specific site measurement. However, the area wide monitoring which has been done for nitrogen dioxide throughout the State of Florida, and more particularly in Lee County, Florida, has never shown that pollutant to exceed ten percent of the maximum limiting level. Moreover, carbon monoxide, hydrocarbons and nitrogen dioxide are felt to decrease at roughly the same percentage rate throughout the years, so that the decrease in the carbon monoxide levels at the project site beyond 1980 would reflect a similar decrease at that site in the amounts of hydrocarbons and nitrogen dioxide. Therefore, if there are no problems with carbon monoxide there is no reason to believe that there would be a problem with hydrocarbons and nitrogen dioxide, nor with the photochemical oxidants which are a bi-product of hydrocarbons and nitrogen dioxide combinations. These opinions stated herein are those of Mr. Davis, and David Barker, Ph.D., an air quality expert who testified in behalf of the Respondent, Lee County Board of County Commissioners, agrees. As indicated, these opinions are well founded. Notwithstanding the belief that the Respondent, Lee County Board of County Commissioners, has complied with the requirements of law, an examination of the Petitioners position would seem to be indicated. The Petitioners' argument against the approval of the Complex Air Source Permit falls into two broad categories. The first of those categories has to do with the allegation that the Respondent, Lee County Board of County Commissioners, failed to comply with the instructions in the application form. After considering the testimony in this cause and the exhibits submitted, this contention on the part of the Petitioners is rejected. The second basis for attacking the application concerns the techniques for gathering and applying the data which was utilized by the Respondent, Lee County Board of County Commissioners, in their efforts to establish reasonable assurances that the project would not violate Ambient Air Quality Standards in terms of the maximum limiting levels set forth in Rule 17-2.06, Florida Administrative Code. To this end, the Petitioners offered a series of competing statistics through their exhibits, in terms of traffic projections. In addition, their expert on air quality, Dr. Detar, was of a different persuasion on the question of the average automobile speed through the signalized intersection U.S. 41 and Daniels Road. In Dr. Detar's mind the average speed would be eight miles per hour as the low average speed for an eight-hour period. In view of all the testimony, this projection of the low average speed is not found to be acceptable. Finally, the Petitioners were of the persuasion that the average mix of automobiles and trucks in the area of the project would be more along the lines of the national average of eighty percent cars and twenty percent trucks. The studies conducted by the Respondent, Lee County Board of County Commissioners, in prior projects demonstrated the efficacy of the ninety- four percent automobiles and six percent trucks standard. In measuring other sources of pollution than sulphur dioxide and particulate matter (which the Petitioners do not question in this case), Dr. Detar believed that hydrocarbons and nitrogen dioxide could be modeled. His explanation of the modeling technique, when contrasted with the argument of the Lee County Board of County Commissioners and the State of Florida, Department of Environmental Regulation, to the effect that those two substances may not be modeled on a specific site basis, failed to be persuasive. In summary, in contrasting the evidence offered in behalf of the Petitioners with that offered in behalf of the Respondent; the Respondent, Lee County Board of County Commissioners, has demonstrated reasonable assurances that maximum limiting levels of the applicable pollutants will not be exceeded in the area of the project. The various memoranda and proposed findings of fact and conclusions of law have been reviewed by the undersigned, and to the extent that those items are not inconsistent with the findings of fact rendered herein and conclusions of law and recommendation, they are hereby acknowledged by the entry of this Order. To the extent that those aforementioned items are inconsistent with the findings of fact, conclusions of law and recommendation by the undersigned, they are rejected.
Recommendation It is recommended that the Respondent, Lee County Board of County Commissioners, be granted a Complex Air Source Permit for the construction of the improvements at Daniels Road, Lee County, Florida. DONE AND ENTERED this 1st day of March, 1979, in Tallahassee, Florida. CHARLES C. ADAMS Hearing Officer Division of Administrative Hearings Room 101, Collins Building MAIL: 530 Carlton Building Tallahassee, Florida 32304 COPIES FURNISHED: E. G. Couse, Esquire Grace & Couse, P.A. Suite 202, Courtney Building Post Office Drawer 1647 Fort Myers, Florida 33902 L. Caleen, Jr., Esquire General Counsel Department of Environmental Regulation Twin Towers Office Building 2600 Blair Stone Road Tallahassee, Florida 32301 Beverly E. Myers, Esquire Assistant County Attorney Lee County Post Office Box 398 Fort Myers, Florida 33902 ================================================================= AGENCY FINAL ORDER =================================================================
The Issue Whether Respondent is in violation of various provisions of Chapter 403, Florida Statutes, as alleged in the Notice of Violation and Orders for Corrective Action dated October 30, 1991.
Findings Of Fact BEI's composting facility is a potential source of water and air pollution and to operate the facility, BEI requires a permit issued by DER. The original permit issued to DER for this facility expired on June 1, 1991 and has not been renewed. Although its permit had expired, BEI was allowed to continue to operate while informal proceedings were ongoing between BEI and DER. When these informal proceedings were terminated by DER on May 20, 1992, further operation of this composting facility was in violation of Chapter 403.707(1), Florida Statutes, and Rule 17-709.400(1), Florida Administrative Code. On at least two occasions while this composting facility was in operation, the air around the facility was polluted by foul odors. During the period following the expiration of BEI's license, BEI failed to submit monthly operating reports and did not conduct quarterly samplings and testing of the compost and submit the testing to DER as required.
Recommendation Based on the foregoing Findings of Fact and Conclusions of Law, it is RECOMMENDED that the Secretary of the DER enter a Final Order finding that BEI has violated Section 403.161(1)(b), Florida Statutes, on each of five counts; and that BEI should immediately cease operation of its solid waste facility, volume reduction plant, until and unless it obtains an appropriate and valid permit from DER and in that regard, BEI shall: Immediately cease acceptance of all materials on the property. In the event that Respondent does not receive a permit from the Department to resume operations at the facility, within 90 days of the effective date of the Final Order, Respondent shall remove all solid waste from the property to an approved solid waste management facility and provide the Department written documentation of its disposal within 30 days of removal. In the event that Respondent does receive a permit from the Department to resume operation at the facility, Respondent shall remain in strict compliance with all terms and conditions of such permit. Within 30 days of the effective date of the Final Order, Respondent shall, if it has not already done so, provide the following to the Department: All records of testing and monitoring conducted on the compost material since January 1, 1990, including daily reports on the temperature and moisture content of compost material, and any testing of compost material conducted prior to distribution. All records documenting application rates of stillage, manure, and leachate to the compost withdrows since January 1, 1990. All records, documenting distribution of composted or mulch material, including amount of compost or mulch material delivered, date of delivery, specific destination of compost or mulch, and intended use of compost or mulch material delivered, since January 1, 1990. All records documenting amount of yard trash received at the facility since January 1, 1990. Within 30 days of execution of the Final Order, Respondent shall make payment to the Department for costs and expenses in the amount of $500.00. Payment shall be made by, cashier's check or money order to the "State of Florida Department of Environmental Regulation". Payment, specifying Office of General Counsel Case No. 91-2006, shall be sent by certified mail to Administrator, Division of Waste Management, Department of Environmental Regulation, 3804 Coconut Palm Drive, Tampa, Florida 33619. DONE AND ENTERED this 16th day of June, 1993, in Tallahassee, Florida. K. N. AYERS Hearing Officer Division of Administrative Hearings The DeSoto Building 1230 Apalachee Parkway Tallahassee, Florida 32399-1550 (904) 488-9675 Filed with the Clerk of the Division of Administrative Hearings this 16th day of June, 1993. COPIES FURNISHED: Tracey S. Hartman, Esquire Department of Environmental Regulation 2600 Blair Stone Road Tallahassee, Florida 32399-2400 Howard C. Batt, Esquire 611 Druid Road East Suite 712 Clearwater, Florida 34616 Virginia B. Wetherell, Secretary Department of Environmental Regulation 2600 Blair Stone Road Tallahassee, Florida 32399-2400 Ken Plante, Esquire General Counsel Department of Environmental Regulation 2600 Blair Stone Road Tallahassee, Florida 32399-2400
The Issue The issues in this case are whether the Gainesville Renewable Energy Center, LLC (GREC) is entitled to an Air Construction Permit from the Department of Environmental Protection (DEP) for the construction of a net 100-megawatt (MW) biomass-fired electrical power plant in Gainesville, Florida, pursuant generally to state rules that relate to the federal Clean Air Act, 42 U.S.C. §§ 7401, et seq. (Clean Air Act), which is administered by the U.S. Environmental Protection Agency (EPA). Specifically, the issues are whether the proposed project satisfies the requirements of Florida's EPA-authorized air program of Prevention of Significant Deterioration (PSD), as set forth in Florida Administrative Code Rule 62-212.400, and Florida's EPA-delegated air program of National Emission Standards for Hazardous Air Pollutants (NESHAP), as set forth in Florida Administrative Code Rule 62-204.800(10) and (11).
Findings Of Fact Introduction On November 30, 2009, GREC filed with DEP an Application for the construction and operation of a net 100 MW (gross 116 MW), biomass-fired electrical power plant at GRU's Deerhaven power plant complex. GREC seeks to place the biomass plant in service on or before December 31, 2013, which is the deadline for eligibility for a federal renewable-energy grant under the American Recovery and Reinvestment Act of 2009. GREC is a subsidiary of American Renewables, LLC, which develops, builds, and operates renewable-energy power plants. American Renewables, LLC, is jointly owned by affiliates of three corporations that develop, operate, invest, and manage various types of energy projects. American Renewables, LLC, recently obtained permits for a similar biomass plant, also net 100 MW, in Nacogdoches, Texas. This plant, which is expected to begin commercial operation in late 2012, has a power purchasing agreement with Austin Energy, a municipal utility owned by the City of Austin. American Renewables, LLC, recently sold the Nacogdoches plant to a subsidiary of Southern Company. GRU is a municipal utility of the City of Gainesville. GRU owns and operates a power generation, transmission, and distribution system to serve its 93,000 retail customers and its wholesale customers, which include the City of Alachua and Clay Electrical Cooperative, Inc. In addition to owning a 1.4-percent share of the Progress Energy Florida Crystal River Unit Three, GRU owns three power supply facilities with a summer capacity of net 608 MW. Of these, the largest is Deerhaven, which generates net 440 MW. A former mayor of the City of Gainesville, Petitioner Bussing served on the utility committee of the City Commission and participated in utility planning for GRU. Petitioner Bussing lives less than 10 miles from the GREC site and regularly walks outdoors, works in his yard, and bicycles in the area. He enjoys canoeing on local waterways and observing wildlife, such as eagles, hawks, and owls. Identifying himself as a "locavore," Petitioner Bussing favors locally grown food. The other petitioners are similarly situated to Petitioner Bussing. Application The findings in this section are generally based on the Application, although some are also based on the Site Application. According to the Application, the GREC site consists of 131 acres within the Deerhaven site in northwest Gainesville and north central Alachua County--eight miles from downtown Gainesville to the southeast and seven miles from downtown Alachua to the northwest. The Site Application states that the Deerhaven site is within a 1146-acre parcel owned by the City of Gainesville. The Site Application notes that the Deerhaven site includes several units. Unit 1 generates 88 MW by a natural gas or oil-fired steam unit. Unit 2, which was certified in 1978, generates 235 MW (sometimes described as 250 MW) by a pulverized coal-fired unit. Unit 3 generates 76 MW by a natural gas or oil-fired, simple-cycle combustion turbine unit. Deerhaven also includes two 19-MW, simple-cycle combustion turbine units. The Application reports that the GREC site abuts the northwest boundary of the GRU's existing generating facilities at Deerhaven. The Site Application identifies the GRU facilities immediately east of the GREC site as an ash landfill, brine landfill, and large stormwater management pond. Abutting these facilities, immediately to their east, are ash settling ponds and a wastewater treatment sludge disposal cell. Abutting these facilities, immediately to their east, is a large coal pile. A spur of the CSX rail line, which is used for coal deliveries to Deerhaven Unit 2, terminates just south of the GREC site. Except for secondary access roads and unpaved trails, no Deerhaven facilities occupy the GREC site. Immediately west of the GREC site is a site used by the Alachua County Public Works Department for an office and other facilities. Also west of the GREC site is a radio tower and undeveloped land. The southernmost extent of the GREC site fronts on U.S. Route 441, which is lined by intermittent commercial and retail uses in this area. Across U.S. Route 441, over one-half mile from the GREC site, is the nearest residential subdivision, which is called Turkey Creek. The Site Application reports that, in the early 2000s, the City of Gainesville purchased an additional 2328 acres of timberland north and east of the Deerhaven site for buffer and potential expansion. The entire area, including the GREC site, was historically devoted to agriculture and pine silviculture, but the GREC site is now occupied by ditches, swales, altered forested communities, and the roads and trails previously mentioned. By groupings from west to east, the proposed improvements on the GREC site are a fuel-storage area, which consists of four separate wood piles; a parking area, offices, a warehouse, a control room, fire pumps, a water treatment facility, and water tanks; a 50-foot wide band of unoccupied land; a switchyard with a transmission line running to a new GRU switchyard at U.S. Route 441, a switchyard control room, steam turbine, fuel day bins connected to the storage area by a conveyor, a boiler, a 230-foot-high stack, a baghouse, and an aqueous ammonia storage area; and a 53-foot-high cooling tower. These components are concentrated on the north side of the site, farthest from U.S. Route 441, and toward the east side of the site, nearest GRU's Deerhaven operations. The boiler, steam turbine, emissions-control equipment, stack, and cooling tower are 3200 feet northwest of U.S. Route 441 and 2200 feet east of the public works facility. The GREC site will also include roads, an administration building, a warehouse, several stormwater detention ponds, water and wastewater treatment facilities, storage facilities for the fly ash and sand from the BFBB, and two emergency diesel engines. The main components of the GREC facility will be a bubbling fluidized bed boiler (BFBB), which will produce steam to power a conventional steam turbine generator for the production of electricity. Except during startup, when the boiler will consume natural gas until it reaches operating temperatures, the BFBB will burn a wide range of clean, woody biomass fuels in a dense, fluidized sand bed at the bottom of the furnace and also in the area above the bed. GREC will obtain the biomass fuel from forest residue (i.e., material remaining after traditional logging), mill residue (e.g., sawdust, bark, and sander dust), precommercial tree thinnings, used pallets, and urban wood waste (e.g., woody tree trimmings from landscape contractors and power-line clearance contractors). Supplementary fuel will be derived from herbaceous plant matter, clean agricultural residues (e.g., rice hulls and straw, but no animal waste), diseased trees, woody storm debris, whole tree chips, and pulpwood chips. However, GREC will not accept any biomass in the form of treated or coated wood, municipal solid waste, coal, petroleum, coke, tires, or construction and demolition waste, about which some doubt arose at the hearing, so GREC represented that it would not accept construction and demolition debris at the facility. The BFBB will combust one million tons per year (tpy) of biomass. To obtain the fuel, GREC will enter into contracts with suppliers within 75 miles of the site. GREC will incorporate in supplier contracts requirements of sustainability and incentives for good stewardship in silvicultural practices. At offsite locations, suppliers will sort, chip and grind, and screen the biomass to design size. After this primary processing, suppliers will deliver the processed biomass to the GREC facility in 130-150 trucks per day. On average, the facility will unload 12 trucks per hour, although it will be capable of unloading trucks at double this rate. Typically, the GREC facility will be open for biomass deliveries 15 hours per day, six days per week. On arriving at the GREC facility, the trucks will proceed to a drive-through structure, which contains three truck dumpers and three receiving hoppers. From the hoppers, the fuel will be conveyed to a fuel processing system, where a metal detector and magnetic separator will remove ferrous metals, a disc screen will remove oversized chips, and a hammer hog will reduce the oversized chips to the design size of three inches or less. This equipment will be located in an enclosed building with a dust-collection system. After this secondary processing onsite, the fuel is conveyed outside to the fuel storage area where it is stored in piles. One wood pile will have an automatic stacker/reclaimer that will be able to deposit, churn, mix, and remove nearly the entire pile. Another wood pile, conical in shape, has a fixed stacker, and the material will be moved by bulldozers and front- end loaders. This rolling stock will transfer some of the wood chips to a smaller, manual-reclaim pile that will also be contoured by bulldozers and front-end loaders. A fourth, much smaller pile will be maintained for the delivery of presized material, mainly sawdust. As originally sized, the wood piles are intended to store sufficient fuel for 15-20 days of operations. In the Site Application, the automatic stacker/reclaimer pile is specified to be 85 feet high, but, after consultation with the Gainesville Fire Department, as detailed below, GREC agreed to reduce the height of this pile to 60 feet. The fixed stacker pile is 60 feet high, and the manual-reclaim pile is 35 feet high. The automatic stacker/reclaimer pile is 400 feet by 400 feet, and the manual- reclaim pile is 400 feet by 465 feet. GREC will manage the separate wood piles to maintain the fuel's design moisture content, which is about 50 percent, but also to ensure that no portion of the stored wood remains in the pile for too long. In general, GREC intends to use fuel on the basis of first-fuel-in, first-fuel-out, to avoid problems of odor and spontaneous combustion, the latter of which is discussed in detail below. The high combustion temperatures reached by the BFBB and the implementation of the requirement for clean woody fuel will, the Application reports, limit the generation of pollutants. Within the 179-foot-high boiler, fluidizing air will expand the combustion zone in the boiler with high turbulence, intimate solids-to-gas contact and a high heat transfer rate in the bed. Staging or overfire air will assist combustion through openings in the furnace walls. Fluidized bed temperatures will range from 1350 to 1700 degrees. (All temperatures are in Fahrenheit.) Temperatures in the overfire air will be 200 degrees hotter to vaporize the volatile gases, such as carbon monoxide (CO) and volatile organic compounds (VOCs). By staging the combustion in the fluidized bed, the formation of thermally induced nitrogen oxides (NOx) will also be reduced. To enhance the air-pollution controls represented by the effective combustion of clean biomass, the GREC facility will employ three additional measures. First, dry sorbent injection (DSI) will inject into the boiler material that, in addition to the calcium that naturally occurs in the ash, will reduce emissions of sulfur dioxide (SO2), sulfuric acid mist (SAM), hydrogen chloride (HCl), and hydrogen fluoride (HF). Second, a selective catalytic reduction (SCR) system will reduce NOx emissions. The SCR system will use a catalyst and a reactant (ammonia gas) to dissociate NOx into nitrogen gas and water vapor. Third, downstream of the boiler, a fabric filter baghouse will reduce emissions of particulate matter (PM) and particulate matter less than 10 microns in diameter (PM10). (Discussed below, PM2.5 is particulate matter less than 2.5 microns in diameter.) As described in the Site Application, the baghouse will comprise 12 filter compartments, each containing 250-350 bags that are six inches in diameter and 14- to 26-feet long. At the bottom of the baghouse will be a hopper to collect ash. As PM forms on the bags, it will form a filter cake that increases the filtration efficiency of the bags. But once the air pressure drops to specified limits, high-pressure air pulses will be directed, automatically, into each bag, loosening the caked fly ash and depositing it as ash in the hopper below. Fly ash from the boiler will be captured by the baghouse filter. Periodically, the fly ash will be collected dry and transported pneumatically to an onsite storage silo. From there--if needed, after stabilization with water--the ash will be transported--enclosed, if still in dry form--for use as a soil supplement or, if such use is unavailable, to an approved offsite landfill. When ash is transferred to trucks, the trucks are sealed, and the air in the trucks displaced by the ash is transferred back to the silo through a vacuum system. Coarser than fly ash, bottom ash will be landfilled, if relatively coarser grained, and transferred pneumatically to the silo, if relatively finer grained. Solid waste from the GREC facility will be transferred ultimately to the New River regional landfill in Raiford, which has a projected life of more than 50 years at current filling rates. The cooling tower will contain a drift eliminator. The purpose of this device is to capture PM/PM10 that has passed the baghouse. The GREC facility will also control PM/PM10 fugitive emissions by the use of pneumatic systems for the delivery of sand for the fluidized bed and sorbent for the DSI to their separate onsite storage silos. According to the Site Application, the City of Gainesville has identified numerous benefits from the GREC project. These include enhancing the integrity and reliability of the GRU generating system, reducing the average age of the GRU generating system, producing reasonably priced electricity, diversifying fuel sources, avoiding the price fluctuations of fossil fuels, hedging the risks of anticipated carbon-constraint legislation (if biomass is treated preferentially under such legislation), reducing construction and operation risks, reducing open burning of biomass products in forestry operations, reducing landfilling of woody biomass, and supporting the silviculture industry. In support of sound silvicultural practices and ecosystem biodiversity, GREC will require all biomass suppliers to adhere to sustainability principles by conforming to the best management practices (BMPs) of the Florida Division of Forestry and will refuse delivery of stumps (to avoid erosion in the source area) and biomass generated from the conversion of natural forests to plantation forests or from nonnative species, unless the nonnative-species biomass is generated from a forest restoration project. Additionally, GREC will pay premiums of $0.50 and $1.00 per ton to suppliers that comply with more ambitious forest stewardship practices. Among the socio-economic benefits of the GREC facility, the Site Application states that construction will generate $48 million of payroll, largely for local and regional labor, and $160 million in nonengineered construction equipment purchases. Facility operations will result in the employment of 44 fulltime employees, initially earning $4 million annually. NonGREC employment will include truck drivers and operators of wood-processing equipment. The Site Application explains that ambient air quality is a product of meteorology, atmospheric chemistry, and pollution emissions. Meteorology controls the distribution, dilution, and removal of pollutants. Atmospheric chemistry controls the transformation of primary pollutants into secondary pollutants. Primary pollutants are discharged directly from the source and, for GREC, will include NOx, SO2, CO, and PM, or, traditionally, soot, although, as a fugitive emission, PM is better considered as dust from the biomass fuel or ash residue. For GREC, the most important secondary pollutant is ozone, which forms from the combination of NOx and VOCs in sunlight. According to the Site Application, EPA has developed an air quality index that describes air quality in relative terms. Good is the highest rating and means that air pollution poses little or no risk. Moderate means that air pollution may be a moderate health concern to a very small number of persons. Unhealthy for sensitive groups means just that, and healthy groups are unlikely to be affected. Unhealthy means that air pollution may cause everyone to begin to experience health effects, and sensitive groups may experience more serious health effects. The two remaining classifications are very unhealthy and hazardous. For 2007, the EPA classified the air quality in Alachua County as 315 days of good, 44 days of moderate, and 6 days of unhealthy for sensitive groups. For 2008, the EPA classified the number of good days as only 258. In general, the EPA classifies the air quality of Alachua County as good with the main pollutant adversely affecting air quality as ozone. The Application analyzes air emissions in light of national ambient air quality standards (AAQS), Title I, Part A, § 109, Clean Air Act, 42 U.S.C. § 7409; New Source Review (NSR) for PSD (NSR/PSD), Title I, Part C, Clean Air Act, 42 U.S.C. §§ 7470-7492; New Source Performance Standards (NSPS) for sources, by category, that contribute significantly to air pollution, Title I, Part A, § 111, Clean Air Act, 42 U.S.C. § 7411--in particular, 40 CFR Part 60, Subparts A, DA, and IIII; and NESHAP, Title I, Part A, § 112, Clean Air Act, 42 U.S.C. § 7412. As discussed in the Conclusions of Law, PSD pollutants are subject to best available control technology (BACT), and hazardous air pollutants (HAPs) are subject to maximum achievable control technology (MACT). The Application reports that the EPA has established national AAQS for six pollutants: SO2, NO2, CO, lead, ozone, and PM, which comprises PM10 and PM2.5. Primary AAQS for these pollutants protect the public health, and secondary AAQS for these pollutants protect the public welfare, such as the environment and physical property. The Application discloses the national and Florida AAQS standards for the six pollutants and reports that the entire state of Florida is in attainment for all six pollutants. This results in the application of the NSR/PSD regulatory framework, rather than a more stringent NSR regulatory framework for areas that are determined to be nonattainment under national AAQS. The Application reports that the GREC facility will be a major facility, under NSR/PSD, because it has the potential to emit more than 250 tpy of a PSD pollutant. GREC must use BACT for all PSD pollutants that will exceed significant emission rates, which are expressed in tons per year by PSD pollutant, and show that its emissions will not violate any national AAQS or PSD increment. If emissions will adversely affect a "Class 1 area," such as a national park or wilderness area, more rigorous protection of the area and national AAQS and PSD increments would be imposed in terms of "air quality related values," but the GREC facility does not impact any of the four Class I areas in Florida. However, all NSR/PSD reviews include assessments of additional impacts on nearby land uses, as well as on soils, vegetation, and visibility. For PSD emissions that exceed their significant emissions rates, GREC must show that a PSD emission, in micrograms per cubic meter, is below what constitutes the PSD's significant impact level, which is, as a measure of ambient concentration, expressed as micrograms per cubic meter. For any PSD emission that exceeds its significant impact level, GREC would have to provide a more elaborate source-impact analysis. According to the Application, the GREC facility is expected to generate the following PSD emissions in the following amounts: NOX--418.1 tpy; SO2--243.9 tpy; CO--715.6 tpy; VOCs--78.1 tpy; PM (filterable)--130.4 tpy; PM10 (filterable and condensable)--281.2 tpy; SAM--5.9 tpy; lead--0.12 tpy; and mercury--0.0084 tpy. (Filterable PM is in a solid or liquid state in the exhaust stream and is subject to capture by a filter. Filterable and condensable PM is in a gaseous state in the exhaust stream and is converted to a solid or liquid state on condensation after passing through a filter.) All of these emissions exceed the significant emission rates except for lead, mercury, and SAM. (Mercury is not a PSD pollutant, but it has a PSD significant emission rate.) Over 95 percent of these emissions are from the BFBB; small amounts are from the diesel emergency generator and firewater pump. As noted below, DEP subsequently determined that GREC could net its SO2 and NOX emissions against offsetting decreases in emissions of these two pollutants by GRU, so that GREC would be required to demonstrate BACT only for CO, VOCs, and PM/PM10. The Application undertakes BACT analysis for PSD pollutants based on a top-down consideration of all available technology, technically feasible control technology in order from the most- to least-stringent, and the applicable control technology, which is both technologically and economically feasible. Because Petitioners' allegations concerning BACT relate only to SO2, NOX, and PM/PM10 emissions, it is unnecessary to consider GREC's BACT analysis for CO and VOCs. The Application also states that GREC will be a major source of HAPs because the GREC facility will emit more than 10 tpy of any individual HAP or more than 25 tpy of total HAPs. As noted below, DEP subsequently determined that GREC's initial projections of HAPs emissions were too high and that, as revised in the February RRAI, discussed below, the HAPs emissions were below both thresholds for a major source, as described below. Because GREC consequently was not required to demonstrate case- by-case MACT, it is unnecessary to consider GREC's MACT analysis. In Alachua County, HAPS are not attributable primarily to stationary fuel combustion. The Site Application states that 86 percent of these pollutants were emitted from mobile and area small sources, such as dry cleaners and gas stations. The Site Application reports that stationary fuel combustion generates about 91 percent of the SO2, about 28 percent of the NOX, about 14 percent of the PM2.5, about six percent of the PM10, and nearly none of the CO and VOCs. Applying 40 CFR Part 60, Subpart DA, which applies to electric utility steam generating units, the Application notes that the BFBB will meet all emissions limits for PM, NOx, SO2, and opacity or visible emissions. Also, the Application states that, to conform to Subpart DA, GREC will have to install with the BFBB an opacity monitoring system, a continuous bag leak detection system for the fabric filters, continuous emissions monitoring systems (CEMS) for SO2, NOX, and oxygen or CO2, and conduct initial performance tests for SO2, NOX, opacity, and PM. The Application states that the GREC emissions are below the significant impact levels for PSD Class II areas for all PSD pollutants except PM10, for which the GREC emissions, on a 24-hour average, will be 20.4 micrograms per cubic meter, as compared to the significant impact level, on a 24-hour average, of 10 micrograms per cubic meter. Thus, the Application analyzes national AAQS and PSD increments only for PM10. Including all significant stack sources of PM10 within 60 kilometers of the GREC facility (fugitive emissions being deemed too local to require consideration) and both stack and fugitive emissions from the GREC facility, the Application concludes that GREC should not be required to perform preconstruction ambient air quality monitoring because Alachua County already performs adequate air quality monitoring for PM10, and the modeling for the 24-hour projections, as opposed to annual projections, shows that GREC's PM10 emissions in excess of the significant impact levels will be highly localized and entirely contained within the Deerhaven site. Additionally, for the 24-hour and annual projections, the Application notes that the maximum distance to significant impacts for PM10 emissions will be only 1.1 kilometers. Referring to the nearest ambient PM10 air quality monitoring site, which is 7 kilometers south of GREC, the Application concludes that, based on modeling for cumulative PM10 impacts, the air quality impacts from all sources, including background, will be substantially below the 24-hour and annual PSD Class II increments and national AAQS, so the GREC facility will not cause or contribute to an exceedance of the PM10 PSD increments or national AAQS. Finally, turning to additional impacts, the Application reports that the GREC emissions are too low to significantly affect soils, vegetation, or wildlife. In discussing PM10 emissions, the Application advises that Florida's 24-hour and annual averages for PM10 emissions, under state AAQS, are 150 and 50 micrograms per cubic meter. As noted above, the GREC facility's PM10 emissions will result in an increase of PM10 concentrations by 20.4 micrograms per cubic meter, on a 24-hour average; its PM10 emissions will result in an increase of PM10 concentrations by 5.3 micrograms per cubic meter, on an annual average. Both of these increases are obviously below the state AAQS. (The national AAQS for PM10 is the same for a 24-hour average and omits an annual average.) Responses to Requests for Additional Information Attachment A to the February RRAI is a set of BMPs for biomass material handling and storage. Attachment A requires GREC to consult with the Gainesville Fire Department and develop a Fire Management Plan. Key components of the Fire Management Plan will be frequent rotation of the biomass and the prevention of biomass compaction. Attachment A provides for the covering or partial enclosing of drop points and conveyor systems for biomass. The in-ground receiving hoppers will be covered by a divided enclosure with roll-up entry doors, curtained exit doors, and stilling curtains in the upper roof. The fuel processing building, which houses the hammer hog and screens, will have local ventilation ducted to a fabric filter dust collector. Drop points to the wood piles will be minimized by telescoping discharge spouts. Boiler fill bins will have vent filters. To ensure that the dust control measures are effective, daily inspections of the equipment will take place. Also, regular maintenance of the equipment will be performed. All major roads at the GREC facility will be paved to suppress fugitive emissions. Trained GREC personnel will promptly remove excessive mud, dirt, or similar debris from paved roads. Attachment A provides that GREC will maintain the wood piles to avoid excessive wind erosion. GREC will develop a dust management plan for the storage areas. GREC will minimize the use of rolling stock on the wood piles during windy conditions. In a request for additional information, DEP commented that the projections of HAPs emissions seemed high because other biomass projects half the size of GREC had projected HAPs emissions one-quarter of those projected by GREC. Noting that 95 percent of the HAPs emissions from the GREC facility would be in the form of HF and HCl, GREC responded that the BFBB manufacturer, Metso Corporation, had recalculated the projected emissions from its boiler based on a redetermination of the fluorine and chloride content of the biomass fuel, BBFB chemical reactions, increased sorbent in the DSI, and optimization and sizing of the baghouse. Based on these recalculations, the February RRAI reports that the GREC facility will emit no more than 25 tpy of HAPs or 10 tpy of any single HAP. The February RRAI states that, based on these recalculations, the GREC will emit 170.7 tpy of SO2 (down from 243.9 tpy) and the following HAPS: HF--9.7 tpy (down from 71.4 tpy; and HCl--9.7 tpy (down from 35.7 tpy). Lead and mercury projected emissions will be the same, but total HAPs emissions will be 24.6 tpy. Also, the February RRAI projects emissions of PM2.5 to be 278.3 tpy. Due to these recalculations of HAPs, the February RRAI states that it is unnecessary for GREC to provide case-by-case MACT. Attachment D to the February RRAI is the Biomass Quality Assurance and Quality Control Plan (Biomass QAQC Plan). Restating the biomass specifications, the Biomass QAQC Plan requires GREC to contract with suppliers for woody biomass material that conforms to the material described in the Air Construction Permit. The Biomass QAQC Plan notes that the power purchase agreement between GRU and GREC requires GREC to hire two professional foresters to manage the biomass procurement. The Biomass QAQC Plan states that GREC is required to inspect each shipment of biomass, upon receipt, and reject all shipments that fail to conform to the specifications contained in the plan. The February RRAI explains why GREC is not required to perform AQRV analysis for impacts to Class I areas. The February RRAI notes that GREC has relocated several improvements by relatively short distances, but these relocations do not affect the PM modeling. The May RRAI mostly addresses PM. The May RRAI accedes to a DEP request to model fugitive emissions after the relocation of various improvements, as mentioned in the February RRAI. GREC supplied this analysis, which suggests that the GREC facility will not cause or contribute to an exceedance of the PM10 PSD Class II increments or national AAQS. Attachment B to the May RRAI describes the dispersion modeling that was undertaken after the relocation of the various site improvements. In response to an EPA comment, the May RRAI adds various offsite sources of PM10, including two simple cycle combustion turbines, three emergency diesel engines, and fugitive PM10 from coal handling at Deerhaven and three simple cycle combustion turbines at another nearby GRU facility. Also, the May RRAI increases the PM10 emission rates for a nearby cement plant. As before, GREC conceded that the PM10 emissions will exceed the PSD Class II significant impact levels, but contended that preconstruction ambient air quality monitoring is unnecessary because adequate data already exist in Alachua County for this pollutant and the 24-hour PM10 impacts will be highly localized and confined with the industrialized areas abutting the GREC site. Additionally, the May RRAI reports the results of cumulative PM10 modeling. Again, the May RRAI states that the result of this cumulative modeling is that the air quality impacts from all relevant sources, including background, will be well below the 24-hour and annual PSD Class II increments and national AAQS, so the GREC facility will not cause or contribute to an exceedance of the PM10 PSD increments or national AAQS. Responding to an EPA comment asking for justification for using PM10 as a surrogate for PM2.5, Attachment C of the May RRAI, citing an EPA guidance memo issued March 23, 2010, explains why PM10 may be used as a surrogate for PM2.5 for the GREC facility. Using the GREC facility's PM2.5/PM10 emission ratios, Attachment C assures that the GREC facility will not cause or contribute to an exceedance of PM2.5 national AAQS. In generating the PM2.5/PM10 emission ratios, Attachment C states that GREC assumed that all of the PM emissions from the BFBB would be PM2.5 because the baghouse filter would capture the larger PM. For fugitive dust and material handling, GREC relied on an EPA published 0.10-0.15 PM2.5/PM10 emission ratio, which is applicable to fugitive dust from paved and unpaved roads, material handling and storage piles, industrial wind erosion, and material transfer operations. GREC selected the 0.15 factor, which assumes a greater presence of PM2.5 in these emissions. For the cooling tower, GREC assumed the same 0.15 PM2.5/PM10 emission ratio. Noting that drift eliminators are the only technology that control PM2.5 and PM10 emissions for wet cooling towers, Attachment C cites a 2002 article finding that a cooling tower's PM2.5 emissions are less than one percent of its PM10 emissions. For its calculations, GREC assumed conservatively that its tower's PM2.5 emissions would be 15 percent of its PM10 emissions. Attachment C restates that, primarily due to the low elevation for fugitive PM emissions, the maximum PM10 impacts would be at the GREC fenceline. However, again taking a worst- case scenario, GREC assumed that all of its PM10 emissions would be stack emissions and that the BFBB PM emissions would coincide with all other PM emissions from the GREC facility. Adjusting the background PM2.5 data to remove the data for 2007, due to the pollution caused by extensive wildfires, GREC determined that, despite all of its conservative assumptions, in some instances resulting in worst-case assumptions, the GREC facility's PM2.5 emissions, when combined with background levels, would be below the 24-hour PM2.5 national AAQS. For this reason, responding to another EPA comment, GREC rejected the need for more additional impacts analysis. DEP's Technical Evaluation On July 14, 2010, DEP issued its Technical Evaluation. The Technical Evaluation identifies four specific elements for the control of fugitive emissions: the use of the first- in/first-out method for biomass and the telescoping chute to minimize drop lengths onto wood pile, use of BMPs and design features to control fugitive emissions from conveyor system, use of enclosures for dust collectors and (where possible) telescoping chutes, and wetting of wood piles and roads, as needed. For the handling of fly ash, the Technical Evaluation notes that a baghouse or similar filter will control fugitive PM emissions from the fly ash silo, and BMPs will be used to minimize PM emissions while loading trucks. For the BFBB, the Technical Evaluation identifies several elements for the control of emissions. The BFBB design, especially its efficient combustion, will control the formation of PM, CO, and VOCs, as well as HAPs. The fabric filter baghouse will control PM2.5 and PM10 emissions. Because the biomass fuel with be low in sulfur, SO2 and SAM emissions will be controlled. These emissions will also be controlled by reaction with the alkaline fly ash and DSI. The SCR will control NOX and VOCs. Low-chloride biomass fuel will control HAPs. HAPs will also be controlled by reaction with alkaline fly ash, DSI, the fabric filter baghouse, and SCR. And drift eliminators will control PM emissions from the cooling tower. The Technical Evaluation finds that the GREC facility is a major stationary source, under NSR/PSD, because it has the potential to emit 100 tpy of any PSD pollutant and is in one of 28 categories of major PSD facilities. The Technical Evaluation explains that, for major modifications of existing major stationary sources, PSD applicability depends on whether significant emission rates will be met. For net emissions exceeding these rates, an applicant must provide BACT for each pollutant exceeding its significant emission rate. The Technical Evaluation notes that PM2.5 is a PSD pollutant, but its significant emission rate has not yet been set, at least in Florida, so PM2.5 is regulated by its precursors and surrogates, including SO2, NOX, and PM/PM10. For the NOX and SO2 emissions of, respectively, 418.1 and 170.7 tpy, the Technical Evaluation discloses that, on July 12, 2010, DEP issued a permit to GRU imposing enforceable reductions in its Deerhaven NOX and SO2 emissions of, respectively, 418 and 171 tpy. In fact, based on a 2007 permit issued to GRU, DEP and GRU expect future reductions at Deerhaven in NOX and SO2 emissions of, respectively, 7139 and 3262 tpy. The air pollution control system permitted in 2007 will, in the long term, result in reductions of SAM and mercury, in excess of the GREC facility's emissions of these two pollutants, but DEP did not consider these offsets because of the lack of CEMS and enforceability. The Technical Evaluation thus concludes that, on a net basis, the GREC facility will emit PM/PM10, CO, and VOCs in excess of their respective PSD significant emission rates. The unnetted emissions of SAM are slightly below its significant emission rate. Although not shown on the table, the emissions of mercury are more than one order of magnitude less than its significant emission rate. Thus, GREC is subject to PSD ambient air modeling and BACT for PM/PM10, CO, and VOCs. The Technical Evolution relies on GREC's revised projections of HAPs with HCl and HF each at 9.72 tpy and total HAPs at 24.7 tpy. The Technical Evaluation concludes that the GREC facility, without regard to the Deerhaven facility, fails to trigger case-by-case MACT review because it is just under the thresholds of 10 tpy for any single HAP and 25 tpy for all HAPs. The Technical Evaluation notes that the 2007 air pollution control system permitted to GRU would result in reductions of HCl and HF greater than GREC's emissions of these two HAPs, but these offsets may not be considered in calculating the HAPs increases from the GREC facility due to the lack of a netting procedure in NESHAP. Reporting that GREC requested that the Air Construction Permit limit NOX and SO2 emissions even though, after netting, such limits were no longer required, the Technical Evaluation compares the GREC facility's emissions caps of these two PSD pollutants with the emissions caps of these two pollutants by other facilities. The GREC facility's emissions caps are lower than most other facilities, including the Nacogdoches biomass plant and another biomass plant in Ft. Gaines, Georgia, which are similar in size to the GREC facility. The biomass for the GREC facility will contain two orders of magnitude less sulfur than the coal burned at Deerhaven. For SAM, DEP imposed a limit of 6.6 tpy because the GREC projection of 5.9 tpy was close to the significant emission rate for SAM of 7 tpy. For the PSD pollutants requiring BACT, the Technical Evaluation observes that GREC has adopted a strategy in the BFBB of emphasizing the control of NOX, even where this means reduced control of VOCs and CO. Noting that the addition of an oxygen catalyst could reduce VOCs and CO, the Technical Evaluation reports that GREC chose instead SCR, which is superior to another system that its affiliate used at the Nacogdoches facility. With the ensuing reductions of NOX, GREC was able to retune the BFBB to back off the NOX control in order to gain additional control of VOCs and CO, which are emitted at slightly lower rates than the rates at the Nacogdoches and Ft. Gaines facilities. Due to the ongoing need to fine tune the BFBB combustion processes and the SCR, the Technical Evaluation notes that GREC agreed to tiered limits of VOCs and CO emission rates. Also, the Technical Evaluation provides that CO compliance will be measured by a CEMS, and VOCs compliance will be measured by an annual test. For PM/PM10/PM2.5, the Technical Evaluation reports that burnout of the constituents of these pollutants is superior in a BFBB than a stoker furnace. Because more-complete combustion reduces the risk of fires in the pollution control equipment, the BFBB permits GREC to use a baghouse to produce lower PM/PM10 limits and to minimize direct emissions of PM2.5. The Technical Evaluation states that the most effective control technologies for PM are fabric filters and electrostatic precipitators, but the former provide better control of fine PM. The Technical Evaluation identifies as supplementary control strategies the minimization of PM2.5 and visible emission precursors by limiting SO2, NOX, ammonia, VOCs, and chlorides. The Technical Evaluation notes that GREC's BACT proposal for filterable PM/PM10 is the NSPS of 89 tpy based on a fabric filter baghouse. The Technical Evaluation adds that GREC estimated 250 tpy for total PM/PM10, including filterable and condensible PM/PM10. Given the BFBB, baghouse, DSI, and SCR, DEP did not expect the emissions of filterable and condensible PM/PM10 to be as high as projected by GREC and expected these emissions to be below those of the Nacogdoches and Ft. Gaines facilities, which projected PM/PM10 emissions at rates about 75 and 43 percent, respectively, of the rate of these emissions at the GREC facility, even though it would emit less NOX and SO2 and would be equipped with a superior catalytic control system. DEP elected the NSPS limit for PM/PM10, but warned that the GREC facility will eventually need to comply with a filterable PM NSPS limit that, when initially proposed by EPA, was about half the emissions rate proposed by GREC. The Technical Evaluation requires compliance by initial and annual stack testing using EPA Method 5 or 17 for filterable PM/PM10 emissions and EPA Method 202 for filterable and condensible PM/PM10 emissions. The Technical Evaluation adds that a visible emissions limit of 10 percent opacity over a six-minute average, except for one six-minute period of not more than 20 percent opacity, which is BACT, will be demonstrated by the continuous opacity measurement system. The Technical Evaluation states that GREC has incorporated BACT into its proposal concerning PM2.5. This finding is based on the BACT limits for PM/PM10, CO, and VOCs; low emissions of SO2 and NOX; enforceable reductions in PM2.5 precursors from Deerhaven; the visible emissions limit, which controls the fraction of PM2.5 that interferes with light transmission; and limits on ammonia and HCl. Controlling SO2, NOX, CO, VOCs, chlorides, and ammonia controls PM2.5 because these pollutants are PM2.5 precursors. For HCl, the Technical Evaluation acknowledges that DSI and the fabric filter will control emissions, for which DEP will require a CEMS. For HF, the Technical Evaluation notes that the fly ash interaction, DSI, and the fabric filter will control emissions, for which DEP will also require a CEMS. For the four metallic HAPs, phosphorus, chromium, manganese, and lead, and nine organic HAPs, which exclude dioxins or furans, DEP will require initial and annual stack tests. For PM, the Technical Evaluation reviews the BMPs for biomass fuel delivery, preparation, storage, and handling. As for the quality of the biomass accepted at the GREC facility, the Technical Evaluation notes that GREC will contractually obligate its suppliers to provide biomass that conforms to the biomass described in the Air Construction Permit. The Technical Evaluation states that GREC must inspect each shipment of biomass and reject nonconforming biomass. GREC must document each shipment and document rejected shipments, including the ultimate disposition of such shipments. Discussing the three PSD pollutants--VOCs, CO, and PM/PM10--that the GREC facility will emit in excess of PSD significant emission rates, the Technical Evaluation approves of GREC's use of PM10 as a surrogate for PM2.5, especially due to the enforceable reductions at Deerhaven of SO2 and NOX. The Technical Evaluation reports that, between 2007 and 2009, Florida's power plants reduced their SO2 and NOX emissions by 38 percent and 54 percent, respectively. Agreeing with GREC that the only pollutant emissions to exceed their significant impact levels will be PM/PM10 for Class II areas, but not Class I areas, the Technical Evaluation also agrees with GREC that no purpose would be served by requiring preconstruction air monitoring for PM because of the low emissions of these pollutants by the GREC facility and the existence of adequate monitoring for PM in Alachua and Putnam counties, which disclose attainment with national AAQS for PM10 and PM2.5. In its multisource PSD Class II increment analysis, the Technical Evaluation explains that the PSD increment is the amount by which new sources may increase ambient ground level concentrations from a baseline concentration. For PM10, the Technical Evaluation agrees with GREC's modeling that the 24- hour and annual averages would not come close to the maximum allowable increment. Likewise, the Technical Evaluation agrees with GREC that its PM10 impacts would not come close to national or state AAQS for this pollutant. Lastly, the Technical Evaluation agrees with GREC in terms of additional impacts. The Technical Evaluation states that the GREC facility will not have an adverse impact on soils, wildlife, or vegetation. The Technical Evaluation reports that the U.S. Fish and Wildlife Service did not require an AQRV analysis due to the facility's low emissions. Based on its analysis, the Technical Evaluation found that the Application, as amended and conditioned by the Air Construction Permit, meets all federal and state air pollution control requirements. Air Construction Permit Draft Air Construction Permit Section 1 highlights the GREC facility's pollution control technology: the efficient combustion of clean woody biomass in the BFBB to minimize formation of PM/PM10/PM2.5 (which is referred to as PM in the draft Air Construction Permit), NOX, CO, and VOCs; limitation of biomass to clean woody biomass to minimize the formation of SO2 and HAPs, including HF and HCl; injection of ammonia into the SCR to SCR to destroy NOX; use of DSI and alkaline fly ash to control SO2, HF, and HCl; installation of fabric filter baghouse to control PM and remove injected sorbents; implementation of BMPs to minimize fugitive PM emissions from biomass handling, storage and processing, ash handling, storage and shipment and alkaline sorbent handling, storage, and processing; and appropriate design of draft cooling tower to minimize drift (PM). For emissions monitoring, draft Air Construction Permit Section 1 identifies the following: CEMS for CO, SO2, NOX, HCl, and HF and a continuous opacity measuring system for visual emissions. Draft Air Construction Permit Section 1 notes that GRU's Deerhaven facility is a major source of HAPs, but the GREC facility itself is not a major source of HAPs. The draft Air Construction Permit states that the GREC facility is a major stationary source under the NSR/PSD program and is subject to NSPS and NESHAP, under the Clean Air Act. Draft Air Construction Permit Section 2, Specific Condition 11 provides: No person shall cause . . . or allow the emissions of unconfined particulate matter from any activity, including vehicular movement; transportation of materials; construction, alteration, demolition, or wrecking; or industrial related activities such as loading, unloading, storing, or handling; without taking reasonable precautions to prevent such emissions. . . . Appendix BMP . . . provides a Best Management Plan of reasonable precautions specific to the GREC facility to control fugitive PM emissions. General reasonable precautions include the following: a. Paving and maintenance of roads, parking areas and yards; b. Application of water or chemicals to control emissions from such activities as demolition of buildings, grading roads, construction, and land clearing; c. Application of asphalt, water, oil, chemicals or other dust suppressants to unpaved roads, yards, open stock piles and similar activities; d. Removal of particulate matter from roads and other paved areas under the control of the owner or operator of the facility to prevent re- entrainment, and from buildings or work areas to prevent particulates from becoming airborne; e. Landscaping or planting of vegetation; f. Use of hoods, fans, filters, and similar equipment to contain, capture and/or vent particulate matter; g. Confining abrasive blasting where possible; and h. Enclosure or covering of conveyor systems. Draft Air Construction Permit Section 3.A applies to the emissions unit of biomass delivery, preparation, storage, and handling. Section 3.A describes the unit as consisting of three truck dumpers, two sets of screens and hogs, and automatic and manual stackers to maintain, on average, a 15-20 day supply of biomass based on full load operation and average biomass fuel moisture content. Noting that suppliers will initially chip, ground, and otherwise process the biomass at offsite locations before trucking it to the GREC facility, Section 3.A reports that 130-150 fuel truck deliveries are expected daily, six days per week. During peak periods, the GREC facility is expected to handle 24 truckloads of biomass per hour. By design, the maximum processing rate is 600 tons per hour with a maximum yearly rate of 1.395 million tons. Draft Air Construction Permit Section 3.A describes the four wood piles. The automatic stacker/reclaimer pile will be 85 feet high--the draft Air Construction Permit does not incorporate the 60-foot height restriction added at the hearing--with a storage capacity of 125,000 cubic yards of fuel. The stock pile will be shaped like a cone, 60-feet high, and capable of storing 8500 cubic yards of fuel. This pile will be fed with a fixed stacker, including a telescoping chute to minimize drop distances. The second storage pile will be 35 feet high with a storage capacity of 79,000 cubic yards of fuel. Rolling stock will transfer fuel from the stock pile to the second storage pile. A fourth, small pile will be for sawdust, which will be delivered, moist, by trucks to an open area adjacent to the second storage pile. Front-end loaders will reclaim the sawdust. Draft Air Construction Permit Section 3.A.1 authorizes the construction of biomass delivery, unloading, and processing equipment consisting of truck scales, a fully enclosed building containing surge bins, size disc screens and hogging equipment, three drive-through truck dumpers with receiving hoppers, six conveyors to transport the biomass from the truck dumpers to the fuel handling and storage system, a metal detector and self- cleaning magnetic separator on the conveyor entering the screen/hog building, two surge bins and two reclaimers within the screen/hog building to accept the biomass from the conveyors from the truck dumpers, two sizing discs in the screen/hog building to screen any oversized biomass and send it to the hogs for reduction to design size, and two hogs in the screen/hog building to reduce the size of any oversized biomass. Draft Air Construction Permit Section 3.A.2 authorizes the construction of biomass fuel handling and storage system equipment consisting of a stacker/reclaimer system for the first storage pile, a telescoping chute for the stock pile, two conveyors to transport the fuel to the stacker/reclaimer pile, a telescoping chute for the stock pile, five conveyors to transfer the fuel from the two storage piles to the BFBB bins, and scales and magnetic separators for some of the conveyors. The two BFBB bins will store sufficient biomass for 45 minutes of boiler operation and will be equipped with bin vent filters to control PM emissions. Draft Air Construction Permit Section 3.A.3 provides for the control of fugitive PM by the use of enclosed conveyors, where practical, and installation of dust collectors on conveyor drop transfer points, also where possible. One exception to the enclosure of the conveyors is a small section near the truck dumpers to allow visual inspection of biomass to ensure that the GREC facility has accepted conforming loads. Section 3.A.3.a requires the addition of a baghouse to the screen/hog building to control PM emissions, and the installation of a screw conveyor to transfer the PM captured in the baghouse to the conveyor taking the biomass to the biomass fuel handling and storage system. Section 3.A.3.b requires the installation of bin vent filters to control PM emissions from the boiler bins. Draft Air Construction Permit Section 3.A.4 requires a BMP plan to control fugitive emissions from this emissions unit. The BMP plan will include provisions to ensure that the biomass conforms to the qualitative standards imposed by the draft Air Construction Permit. A draft BMP plan is attached to the draft Air Construction Permit, but GREC must provide DEP with a final BMP plan at least 180 days prior to opening the facility. The draft BMP plan addresses fugitive emissions, pile management, and fire prevention. After reciting the clean woody biomass materials that are permitted, as noted above, the draft BMP plan prohibits wood that has been chemically treated or processed, yard trash, paper, treated wood such as CCA or creosote, painted wood, and wood from landfills. The draft BMP plan does not explicitly prohibit the acceptance of construction and demolition debris, although GREC offered at the hearing to add this prohibition. The draft BMP plan requires the covering or partial enclosure of conveyor systems and drop points for biomass. The hoppers into which biomass trucks deliver their loads must be covered for dust control. The hoppers will be in a divided enclosure with roll-up entry doors, slitted curtains at the exit doors, and stilling curtains in the upper roof area. Processing equipment will be in an enclosed building, identified above as the screen/hog building, which will be equipped with local ventilation and ducted to a fabric filter dust collector. Drop points to the wood piles will be designed to minimize the overall exposed drop height by using telescoping discharge spouts. Boiler fuel bins must be equipped with bin vent filters. GREC staff will conduct daily observations of the conveyor system and drop point integrity to ensure proper operation. All major roads at the GREC facility will be paved. GREC staff will promptly remove excessive mud, dirt, or similar debris from the paved roads. All paved roads and gravel areas will be wetted as needed to minimize fugitive dust emissions. GREC shall manage and maintain the biomass storage areas to avoid excessive wind erosion. Ninety days after the plant becomes operational, GREC shall submit to DEP a fugitive dust management plan for the biomass storage area. Front-end loaders and other equipment will minimize movement of the biomass on high wind event days. When necessary to minimize fugitive dust emissions, GREC will wet the biomass before moving it with front-end loaders and other equipment. GREC staff shall observe the biomass storage areas daily to determine if they need to implement elements of the fugitive dust management plan. GREC staff will work with the Gainesville Fire Department to develop a Fire Management Plan. GREC will avoid spontaneous combustion and odors by rotating the biomass in the wood piles. The stacker/reclaimer pile will be divided into zones to facilitate the removal of the oldest biomass first. The fuel yard manager will do the same with the manual pile. Compaction of the biomass will be minimized. To assure that the qualitative biomass specifications are met, GREC will require that suppliers perform most of the processing offsite. For each shipment of biomass, GREC must record the date, quantity, and description of the material received. GREC must inspect each shipment for nonconforming materials, and GREC must reject or segregate such material, if it is discovered. GREC must maintain records of rejected shipments and their disposition. Draft Air Construction Permit Section 3.A.6 specifies the qualitative standards for the biomass. GREC may receive only "in-forest residue and slash," which are defined as "tops, limbs, whole tree material and other residues from soft and hardwoods that result from traditional silvicultural harvests"; "mill residue," which is defined as "saw dust, bark, shavings and kerf waste from cutting/milling whole green trees; fines from planing kiln-dried lumber; wood waste material generated by primary wood products industries such as round-offs, end cuts, sticks, [and] pole ends; and reject lumber as well as residue material from the construction of wood trusses and pallets"; "pre-commercial tree trimmings and understory clearings," which are defined as "tops, limbs, whole tree material and other residues that result from the cutting or removal of certain, smaller trees from a stand . . .; and forest understory which includes smaller trees, bushes and saplings"; "storm, fire and disease debris," which are defined as "tops, limbs, whole tree material and other residues that are damaged due to storms, fires or infectious diseases"; "urban wood waste," which is defined as "tree parts and/or branches generated by landscaping contractors and power line/roadway clearance contractors that have been cut down for land development or right-of-way clearing purposes"; "recycled industrial wood," which is defined as "wood derived from used pallets packing crates; and dunnage disposed of by commercial or industrial users"; and "supplementary fuel material," which is defined as "herbaceous plant matter; clean agricultural residues (i.e. rice hulls, straw, etc.: no animal wastes or manure); and whole tree chips and pulpwood chips." Draft Air Construction Permit Section 3.A.8-13 describes visible emissions limits and opacity testing that GREC must perform. The description conforms to the limits described above. Draft Air Construction Permit Section 3.B applies to the BFBB. Section 3.B provides that the maximum heat input capacity is 1358 mmBTU per hour on a four-hour average basis. The BFBB's steam production capability will be 650,000 to 930,000 pounds per hour. Section 3.B repeats the description of the pollution-control technology contained in the introduction of the draft Air Construction Permit, adding only that the fabric filter baghouse will have a design efficiency of 99.99 percent to control PM and visible emissions. Draft Air Construction Permit Section 3.B describes the stack as 12 feet in diameter and at least 230 feet tall. It will release flue gas with a temperature of about 310 degrees at a volumetric flow rate of 520,600 actual cubic feet per minute. Draft Air Construction Permit Section 3.B requires CEMS for CO, NOX, SO2, HCl, and HF, as well as continuous opacity monitoring systems for visible emissions. Draft Air Construction Permit Section 3.B.1 describes the BFBB. Section 3.B.2.a requires the addition of a fabric filter baghouse to control PM and visible emissions. Section 3.B.2.b requires the addition of an ammonia-based SCR to reduce NOX emissions. Section 3.B.2.c requires the addition of DSI to control the emissions of SO2 and HAPs, particularly HCl and HF, although there seems to be no mention of the trona sorbent that GREC selected, after submitting the original application, to achieve greater pollution control. The 24-hour average from CEMS of SO2, HCl, and HF will be monitored daily by trained staff to determine if adjustments are required to DSI to assure that emissions of these pollutants do not exceed the limits stated in the draft Air Construction Permit. GREC must report these emissions data quarterly to DEP. Draft Air Construction Permit Section 3.B.9 states the emissions limits for the BFBB and the applicable tests. Selected limits are: NOX--416.4 tpy--12-month CEMS; SO2--170.7 tpy--12-month CEMS; SAM--1.4 lb/hr--initial and annual stack test; CO--0.12/0.18 lb/mmBTU--30-day CEMS; HCl--9.72 tpy-- 12-month CEMS; HF--9.72 tpy--12-month CEMS; HCl, HF, organic HAPs, and metallic HAPs--24.7 tpy--12 month CEMS plus initial and annual stack tests; visible emissions--10 percent opacity-- continuous opacity monitoring system and initial stack test; VOCs--0.01/0.009 lb/mmBTU--initial and annual stack test; and heat input rate--1,358 mmBTU/hr--four-hour average. "Lb/mmBTU" means pounds per million BTU heat input. The alternative values for CO and VOCs state the limit for the first 360 calendars after certification of the CEMS followed by the limit thereafter and allow GREC time to fine tune the BFBB and air pollution control technology. Draft Air Construction Permit Section 3.B.13 requires GREC to install, calibrate, maintain, and operate CEMS for SO2, NOX, CO, HCl, and HF, as well as a diluent monitor for either CO or oxygen, from the boiler stack to show compliance with Section 3.B.9. This section provides the standards for certification, operation, maintenance, and recordkeeping for each CEMS. Draft Air Construction Permit Section 3.B.18 provides that the initial and annual stack tests shall be conducted between 90 and 100 percent of maximum heat input rate. A note states that the initial test must be done at 90 to 100 percent of permitted capacity, but the draft Air Construction Permit will be modified to reflect true maximum capacity, as constructed, so, implicitly, the annual tests will be based on the adjusted maximum heat input rate. Draft Air Construction Permit Section 3.B.19 provides similarly for HAPs. Draft Air Construction Permit Section 3.B.20 identifies the EPA Method stack tests and calculations for various emissions. EPA Method 320 is for the measurement of Vapor Phase Organic and Inorganic Emissions by Extractive Fourier Transform Infrared Spectroscopy. EPA Methods 5, 5B, and 17 are for the measurement of PM. EPA Methods 201 and 201A are for the measurement of PM10. All but one of the EPA Methods are specified in 40 CFR Part 60, Appendix A. Despite the statement in the Technical Evaluation that DEP would require GREC to use EPA Method 202 to measure filterable and condensible PM emissions, the draft Air Construction Permit omits this test, as well as any other test for filterable and condensible PM emissions. Draft Air Construction Permit Sections 3.B.22 and 23 require GREC to continuously measure and record pressure drops across each baghouse compartment controlling PM boiler emissions. Draft Air Construction Permit Section 3.B.25 specifies the information to be contained in the stack test reports submitted to DEP. Section 3.B.26 provides that GREC will submit to DEP monthly records of the hours of operation of the BFBB, tons of woody biomass burned, cubic feet of natural gas burned (for start-ups), pounds of steam, total heat input rate, hourly heat input rate to the BFBB, and the updated 12- month rolling results for each of these parameters. Draft Air Construction Permit Section 3.B.27 provides that GREC will submit to DEP quarterly records of CO, NOX, SO2, HCl, HF, and opacity emissions. Draft Air Construction Permit Section 3.C pertains to ash handling, storage, and shipment. Section 3.C states that about two-thirds of the ash created by the combustion of the biomass will leave the BFBB as fly ash and the remaining one- third will leave as bottom ash. Fly ash from the boiler connective pass and baghouse hoppers will be collected dry and transported pneumatically to a single fly ash storage silo by means of two vacuum blowers. The transferred fly ash will first pass through a receiver/collector that will separate the fly ash from the conveying air stream. After passing through an air lock valve, the fly ash will be deposited into the storage silo, which will be vented through a baghouse to control PM emissions. The fly ash will either be stabilized with water or loaded dry into a receiving truck. If stabilized with water, the ash will be transferred by chute into covered trucks, which will haul it offsite for reuse or disposal. If transferred dry, the ash will be transferred by an enclosed process by chute into sealed trucks. Draft Air Construction Permit Section 3.C states that bottom ash from the bed will consist primarily of noncombustible materials (e.g., rocks, glass, sand, and metal) from the biomass fuel. The coarse bottom ash will be removed from the BFBB through ash hoppers and chutes. The coarse material will be sieved in a rotating screen prior to conveyance to the bottom ash container. The contents of this container will be taken offsite for disposal at a properly licensed landfill. Draft Air Construction Permit Section 3.C.1 authorizes GREC to construct an emissions unit consisting of the above-described equipment for the handling, storage, and shipment of fly and bottom ash. Section 3.C.2 requires GREC to install and operate, where practical, enclosed conveyors for bottom and fly ash to minimize fugitive PM and, where practical, dust collectors on the bottom and fly ash transfer points, drop points, hoppers, and chutes. Section 3.C.2 requires GREC to design, install, and maintain a baghouse to remove PM from the fly ash storage silo exhaust. This baghouse will achieve a PM emission rate of 0.15 grains per dry standard cubic foot. Draft Air Construction Permit Section 3.C.4 provides that the maximum design transfer rate of the fly ash handling system will be 3.2 tons per hour with a maximum annual design transfer rate of 27,594 tpy. Section 3.C.5 provides that the maximum design transfer rate of the bottom ash handling system will be 1.5 tons per hour with a maximum annual design transfer rate of 13,140 tpy. The overall ash handling, storage, and shipment system will have a maximum annual design transfer rate of 40,734 tpy. Draft Air Construction Permit Section 3.C.7 imposes a 10 percent opacity limit from the bottom and fly ash conveyors, transfer points, drop points, hoppers, chutes, and dust collectors, except for a 20 percent rate for one six-minute period per unspecified period of time. Section 3.C.8 limits PM emissions from the baghouse of the fly ash silo to 0.15 grains per dry standard cubic foot. Draft Air Construction Permit Sections 3.C.11 and 12 pertain to initial and annual testing for visible emissions. Section 3.C.13 provide that these tests sill serve as a surrogate for PM emissions tests. If the visible emissions standard is unmet, a PM test using EPA Method 5 must be conducted on the baghouse stack to show compliance with the PM emissions standard specified in Section 3.C.8. Section 3.C.14 requires GREC to maintain continuous operation of bag leak detection systems on the fly ash storage silo baghouse. Draft Air Construction Permit Section 3.D describes the cooling tower as a four-cell, mechanical, draft-type tower with high efficiency fill and drift eliminators. Cooling tower evaporation loss at maximum load is estimated to be 1.34 million gallons per day. GREC will obtain makeup water from two onsite wells drilled to the Floridan aquifer. Draft Air Construction Permit Section 3.E describes an emergency diesel generator with a maximum design rating of 564 kW. Draft Air Construction Permit Section 3.F describes an emergency diesel firewater pump engine with a maximum design rating of 275 hp. In addition to the draft BMP plan, described above, the draft Air Construction Permit contains several other appendices. Appendix CEMS requires GREC to evaluate the acceptability of each CEMS by conducting a performance specification. Appendix CEMS Section 8 provides: for CO CEMS, GREC will use EPA Performance Specification 4 or 4A; for NOX and SO2 CEMS, GREC will use EPA Performance Specification 2; for HCl, GREC will use EPA Performance Specification 15, Method OTM 22, or alternative specification approved by DEP; and for HF, GREC will use EPA Performance Specification 15, Method OTM 22, or alternative specification approved by DEP. The EPA performance specifications are found at 40 CFR Part 60, Appendix B. Appendix CEMS Section 9 requires GREC to implement EPA quality assurance procedures found at 40 CFR Part 60, Appendix F. These apply to each pollutant mentioned in the preceding paragraph. Appendix CTR covers common testing requirements. Appendix CTR Section 1 requires that emissions tests take place with the emissions unit, such as the BFBB, operating at permitted capacity, which is defined as 90 to 100 percent of the maximum operation rate allowed by the final Air Construction Permit. Appendix CC covers common conditions. Appendix CC Section 10 provides that GREC will comply with changes in Florida statutes and DEP rules after "a reasonable time for compliance." Other Findings Dioxin Petitioners claim that GREC has failed to provide reasonable assurance that the proposed facility protects public health and the environment from emissions of dioxins, including furans and PCBs, and the draft Air Construction Permit fails to impose emissions limits for dioxins. Dioxins are not among the pollutants covered under national AAQS. Dioxins are classified as HAPs, but, unlike the situation with HCl and HF, Petitioners do not contend that DEP incorrectly concluded that dioxin emissions would be under 10 tpy. Instead, Petitioners claim that the projected emissions of dioxins by the GREC facility, although indisputably well under 10 tpy, are nonetheless high enough to endanger public health and the environment. Dioxins are compounds that result from the combustion of chlorine-containing materials, including wood. The family of "dioxins" includes furans and polychlorinated biphenyls (more commonly known as PCBs), which all are within the family of persistent organic pollutants. Common sources of dioxins include boilers, electrical power plants, municipal and medical waste incinerators, crematoriums, cement kilns, forest fires, household fireplaces, cigarette smoking, pulp production, and open burning. Dioxins have been associated with cancer and disorders of the immune, skin, digestive, and reproductive systems, where dioxins may act as endocrine disruptors. Work with rats suggests that a major effect of excessive dioxin exposure in utero is upon the reproductive system of the fetus. Dioxins are persistent. Their half lives in the environment range from 30 to 40 years. Because they are hydrophobic and accumulate in fatty tissue, dioxins enjoy half lives of 7-12 years in humans. Humans acquire dioxins by breathing, skin contact, consuming water, consuming food, breastfeeding, and transplacental movement while in utero. The last three means are the principal routes of human exposure. The virtually safe dose, or reference dose, for dioxins is low: one picogram per kilogram per day. One picogram is one-trillionth of one gram. An EPA work in progress may lower this reference dose to 0.7 picograms per kilogram per day. For the late 1990s, the EPA estimated that the average American acquired 6-10 picograms per kilogram per day, later reducing this estimate to 6-8 picograms per kilogram per day. The EPA estimate for children, including breast-fed infants, is five to seven times higher, around 40 picograms per kilogram per day. This is about 60 times higher than the virtually safe dose. However, the trends for dioxin levels are good. In its 2006 reassessment of dioxin, the EPA reported that dioxin levels in the environment had decreased by over 90 percent since the late 1980s. Over roughly the same period, the Centers for Disease Control reported that dioxin concentrations in human blood had decreased 80 percent, although decreases in dioxin concentrations in human fatty tissue over the same period of time are likely less. To some extent, dioxin emissions will be limited by the pollution control equipment, especially the redesigned fabric baghouse and SCR catalyst, which, according to the Technical Evaluation, will help destroy VOCs and is a documented strategy for dioxin control. Also, the temperature of the air leaving the stack will be about 310 degrees--90 degrees below the temperature at which dioxins form. GREC has provided reasonable assurance that the GREC facility will not emit dioxins in significant amounts. Thomas Davis is the principal engineer of GREC's consultant, ECT. Mr. Davis, who has considerable experience in air pollution control technology, analyzed the potential for dioxin emissions from the GREC boiler. Mr. Davis found five, operational fluidized bed boilers for which relevant data were available on the rate of dioxin emissions. He then applied the derived emissions rate to the GREC boiler. Mr. Davis determined that the GREC boiler will likely emit .11 grams per year of all dioxins and about .012 grams per year of 2,3,7,8 TCDD, the most potent dioxin. Expressed in another way, the .11 grams per year of total dioxins emitted by the GREC boiler is 110,000,000,000 picograms per year or 301,369,860 picograms per day. If the average person--young and old--weighs 50 kilograms, this emission rate translates to about 6 million picograms per kilogram per day. If the population of Alachua County were 250,000 persons, then the daily exposure, without regard to dispersion patterns, would be 24 picograms per day. For many reasons, 24 picograms of dioxins per kilogram per day of exposure represents only a starting point in the calculations necessary to grasp the limited extent of the dioxin exposure posed by the GREC boiler. An adjustment of one order of magnitude is suggested by the fact that Mr. Davis calculated the emissions rate of most toxic 2,3,7,8 TCDD at one- tenth the rate of the dioxins family. This means that the most toxic dioxin is produced at the rate of only 2.4 picograms per kilogram per day. A larger adjustment is required because the GREC biomass plant will displace substantial open burning that presently takes place in North Florida. The result will be a large net reduction in dioxin emissions. How much and over what area is hard to say, partly due to the replacement of dispersed burning with point-source combustion. The record supports an estimate that about half of the biomass to be combusted by GREC would have been open burned. Using this estimate, the open burning of this biomass would have produced dioxin emissions of 3-8 grams per year. GREC has effectively replaced these dioxin emissions with .11 gram per year. And, if the dispersed dioxin emissions displaced by the GREC facility were closer to agricultural areas, given the role of food consumption, not inhalation, as the primary means of consumption, another adjustment downward in effective dose would be necessary. Calculations by two witnesses support GREC's reasonable assurance of the insubstantiality of the impact posed by the GREC boiler in terms of dioxins. Mr. Davis calculated dioxin dispersal patterns for air and deposition and found that the average annual maximum concentration was .000000000149 micrograms per liter of air per and the average annual wet and dry deposition rate was .0000000000206 grams per square meter. These are reassuringly low numbers. Making more elaborate dioxin calculations, Dr. Christopher Teaf, an expert in environmental chemistry, toxicology, and human health risk assessment, performed a large number of calculations in the most conservative manner possible, such as by assuming that all dioxins were 2,3,7,8 TCDD and treating the emissions from the GREC boiler as new emissions (i.e., disregarding the fact that GREC's dioxin emissions displace far higher dioxin emissions from open burning). Dr. Teaf showed that air concentrations and wet and dry deposition rates were well below--usually, by one or more orders of magnitude--recently published EPA regional screening levels for air, water, and soil. Petitioners' contention for a limitation on dioxins emissions in the Air Construction Permit misses a couple of points. The GREC boiler will result in a net reduction in dioxin emissions, and, even without regard to the netting, GREC has provided reasonable assurance that the GREC facility's dioxin emissions are not, themselves, significant. GREC has provided reasonable assurance that the GREC facility adequately protects the public health and environment from emissions of dioxins, including furans and PCBs, and, based on the circumstances of this case, the Air Construction Permit is not required to contain a dioxins emissions limit. Mercury Petitioners claim that GREC has failed to provide reasonable assurance that the proposed facility protects public health from emissions of mercury. Mercury is not among the pollutants covered under national AAQS. Although not a PSD pollutant, as noted above, NSR/PSD sets a significant emission rate for mercury, and the mercury emissions of the GREC facility will not exceed this rate. Although a HAP, mercury, like dioxins, is not emitted at rates anywhere near the 10 tpy threshold. Instead, as with dioxins, Petitioners claim that the projected emissions of mercury by the GREC facility, although indisputably well under 10 tpy, are nonetheless high enough to endanger public health and the environment. The biomass fuel contains trace amounts of mercury. Combustion at 1500 degrees vaporizes the mercury into gaseous elemental mercury. Subsequent cooling may produce elemental mercury, particle-bound mercury, and oxidized mercury compounds, which is also known as reactive gaseous divalent mercury (RGM). The baghouse filters might capture some of these mercury emissions, although GREC's analysis conservatively assumed that they would not. Of the 16.7 pounds per year of all forms of mercury projected to be emitted by the GREC biomass plant, about 70 percent of it, according to GREC's conservative assumptions, will be elemental mercury and 30 percent of it will be RGM. The former has long residence time in the atmosphere and travels long distances, and the latter deposits locally and regionally. By comparison, annual anthropogenic emissions of mercury in the United States were 145 tons in 2005, including 48 tons from power plant emissions. In 1999, mercury emissions from Florida coal-fired plants were 1923 pounds. Worldwide, anthropogenic emissions of mercury account for two-thirds of total mercury emissions, the remainder being from natural causes, such as volcanic eruptions and oceans. The Site Application considers wet and dry deposition rates of mercury in the Santa Fe River basin. After calculating an average areal wet deposition rate from the GREC facility, the Site Application concludes that it is 6000 times less than the average areal wet deposition at the nearest location for which such data are available. The Site Application also concludes that the wet plus dry deposition rate of mercury from the GREC facility will be 400 times less than the wet-only rate at the comparison location. Additionally, as noted above, the air pollution control system installed at Deerhaven will reduce mercury emissions by more than the increases caused by the GREC project. Because these decreases will not be subject to CEMS and will not be enforceable, DEP's NSR/PSD analysis could not net the GREC facility's mercury emissions against the corresponding decreases in mercury emissions at Deerhaven. However, the GREC facility will emit mercury at a rate over one order of magnitude less than the PSD significant emission rate for mercury. And, to the extent that Petitioners have questioned the safety of GREC's projected mercury emissions outside of NSR/PSD and NESHAP, then the limitations on netting do not preclude attaching significance to the fact that, when considered in conjunction with roughly contemporaneous pollution control improvements at Deerhaven, the GREC facility's mercury emissions are nonexistent. GREC has provided reasonable assurance that the GREC facility adequately protects the public health and environment from emissions of mercury. Netting of NOX and SO2 To Avoid BACT Petitioners claim that DEP improperly allowed GREC to net its NOX and SO2 emissions against enforceable reductions of NOX and SO2 by GRU at Deerhaven, so as to avoid BACT analysis. On July 12, 2010, DEP issued a permit to GRU imposing enforceable and permanent reductions on Deerhaven Unit 2's emissions of NOx and SO2--418 tpy of the former and 171 tpy of the latter. These reductions were achieved by GRU's installation of more effective pollution control technology. Under NSR/PSD, GREC may net out its emissions of NOx and SO2 by taking into account these offsetting GRU reductions because GREC and GRU constitute one major stationary source, under NSR/PSD permitting. Offsetting the increased emissions of GREC with the decreased emissions of GRU is authorized by the proximity of the two operations and their common operational control. Specifically, GRU controls GREC's operations through their power purchasing agreement, which gives GRU the authority to dispatch the power generated by the GREC facility, to determine when the biomass plant will start up and shut down, to control the amount of electricity that the GREC biomass plant will produce while operating, and to regulate the voltage of such electricity. GRU will supply the switchyard and transmission lines by which GREC-produced power will enter the power grid and will distribute GREC-produced power among GRU customers. GRU will also supply the natural gas that GREC requires for start-up and the electricity that GREC requires for start-up and stand-by operations. GRU even agreed to reduce its groundwater withdrawals by 1.4 million gallons per day, so GREC could withdraw an equal amount of groundwater for its operations. Contrary to Petitioners' contention, this aggregate treatment of GRU and GREC is not a legal fiction designed to circumvent BACT under the NSR/PSD program. On these facts, it would be much easier to prove that the independence of GREC is a legal fiction, or that GREC serves as GRU's contractor, ushering the biomass plant through certification, permitting, the acquisition of supplier contracts, and start-up, perhaps then to sell it to GRU at the same late stage that GREC's affiliate sold the Nacogdoches plant. But whatever the precise relationship between the two entities is, or proves to be, at this stage, without doubt, GRU controls GREC. Contrary to Petitioners' contention, the emissions reduction achieved by GRU at Deerhaven cannot somehow be disregarded in this case and "banked" as a gain in achieving cleaner air. From all appearances, GRU pursued this emissions reduction--and certainly the permit modification enforcing the emissions reduction against GRU permanently--for the same reason that it agreed to reduce its groundwater withdrawals. The reason is not an abundance of good will among corporate partners working shoulder to shoulder in providing America's power needs or a gestalt moment of environmental awareness. GRU effected this emissions reduction as a strategic decision to enable GREC to come online sooner and provide GRU with a reliable source of power from a plant much newer than any that it has in place at Deerhaven. This is the economic reality of the closer-than- armslength relationship that exists between GRU and GREC. The netting of NOx and SO2 emissions means that GREC effectively emits no such pollutants. But to put GREC's offset emissions into context, Deerhaven Unit 2 produces roughly 2.5 times the power that the GREC plant will produce. Even after the July 2010 emission reductions, Deerhaven Unit 2 is permitted to emit 3381 tpy of NOx emissions and 8005 tpy of SO2 emissions. If the GREC plant were scaled up to Deerhaven Unit 2's capacity and the NOX and SO2 emissions could be extrapolated linearly, the GREC biomass plant would produce about one-third as much NOx and one-twentieth as much SO2. Nothing in the record suggests that GREC's relatively low emissions of NOx and SO2--even without regarding to netting--presents a significant risk to human health or the environment. GREC has provided reasonable assurance that its NOx and SO2 emissions properly should be netted against offsetting reductions in these emissions at Deerhaven and that BACT analysis for these pollutants is thus unnecessary. Not Major Source of HAPs So No MACT Petitioners claim that DEP improperly determined that the GREC facility will not be a major source of HAPs, so DEP improperly relieved GREC of the burden of demonstrating case-by- case MACT. As noted above, originally, GREC stated that its emissions of HCl and HF, as well as total HAPs, were sufficiently high to trigger MACT case-by-case review. Originally, the HCl and HF emissions were projected to be 36 tpy and 71 tpy, respectively, and total HAPs were 114 tpy. However, after DEP representatives advised GREC representatives that their HCl and HF projections seemed very high, based on DEP's experience with comparable facilities, GREC representatives met with representatives of the boiler manufacturer, Metso, to determine if they could implement more stringent emission control technology. The purpose was to reduce HAPs emissions to levels more in line with DEP's experience, which would be sufficiently low to avoid triggering MACT case-by-case review. The means by which GREC and Metso achieved this reduction essentially constituted MACT. The difference was that, by following DEP's recommendations, GREC was able to avoid months of formal MACT analysis. On February 2010, GREC presented to DEP a revised set of projections of HAPs emissions that were just beneath the MACT thresholds of 10 tpy for any single HAP and 25 tpy of all HAPS. As noted above, the revised projections are for 9.72 tpy of HCl and HF, each, and 24.7 tpy of all HAPs. GREC justified these revised projections by several means. First, Metso reconsidered the chlorine and fluorine concentrations in the clean woody biomass to be received by the GREC facility, reevaluated the chemical reactions, and reduced its earlier assumptions. Second, Metso and GREC selected for the DSI a more effective sorbent, trona, which reduces the emissions of HF and HCl. Third, Metso and GREC increased the amount of sorbent to be injected into the flue gas system, which will further reduce emissions of HF, HCl, and SO2. Fourth, Metso and GREC changed the catalyst in the SCR, which will remove HAPs more effectively. Fifth, Metso and GREC increased the size and optimized the design of the fabric filter baghouse, which will further reduce stack emissions of PM, but also HAPs to a lesser degree. These are not paper adjustments, but are actual investments in technology that will cost GREC millions of dollars. Petitioners, though, remain skeptical, partly due to the proximity of the revised projections to the regulatory thresholds. For HF, at least, the skepticism is clearly misplaced. The actual projection for HF emissions is much less than 9.72 tpy. Metso and GREC selected 9.72 tpy for HF to allow for a margin of error in the projections. GREC's motivation was obviously to a avoid a sub-threshold breach of a projected emissions limit and the resulting regulatory intervention of DEP. Metso's motivation probably arises from the fact that, to induce GREC to purchase its boiler, Metso provided GREC a guarantee that, at least initially, the boiler will meet these revised HAPs emissions limitations. So, the proximity to regulatory thresholds, at least for HF, is not a ground for skepticism. As revised, the pollution control systems restrict HAPs, and other pollutants, as follows: 1) good combustion practices in the BFBB control PM, CO, VOCs, and HAPs generally; 2) the fabric filter baghouse controls emissions of PM10, PM2.5, and HAPs; 3) clean biomass fuel, reaction with alkaline fly ash, and DSI control SO2 and SAM; 4) ammonia-based SCR controls NOx, VOCs, and HAPs generally; and 5) high-efficiency drift eliminators in the cooling tower control PM. Assurances that these close margins for the HAPs thresholds, as well as the other pollutant limits, will not be breached is also supplied by the CEMS: for SO2 and NOx, 24-hour, 30-day, and 12-month CEMS; for SAM, an initial and annual stack test; for CO, a 30-day CEMS; for HCl and HF, an initial stack test and 12-month CEMS; for HAPs generally, an initial and annual stack test and 12-month CEMS; for PM/PM10, an initial and annual stack test; and for visible emissions and VOCs, an initial and annual stack test, as well as continuous opacity monitoring. Finally, the GREC facility's HAPs emissions are offset by decreases in emissions of HCl and HF, as well as SAM and mercury, as a result of the enhanced pollution control technology adopted by GRU at Deerhaven. Although these reductions, which are all greater than the emissions of these pollutants by the GREC facility, are not enforceable and netting is unavailable under NESHAP, these reductions are relevant in assessing Petitioners' broader claims concerning human health, again outside of the context of NESHAP. GREC has provided reasonable assurance that its facility will not emit more than 9.72 tpy annually of any individual HAP or 25 tpy of all HAPs. Thus, DEP properly determined that case-by-case MACT analysis was unnecessary. Stack and Diesel-Exhaust Emissions of PM/PM10 and Failure to Require BACT Petitioners claim that the draft Air Construction Permit inadequately accounts for stack and diesel-exhaust emissions of PM and PM10 and fails to require BACT for these pollutants. In one respect, Petitioners' claim is correct. The failure of the draft Air Construction Permit to incorporate the provision of the Technical Evaluation that DEP would require GREC to measure filterable and condensible PM with EPA Method 202, in conjunction with the apparent absence of any other test for filterable and condensible PM, is, literally, inadequate accounting for stack emissions of PM/PM10, at least where such a test is commonly enough available to be identified as an EPA Method. But DEP can easily repair this defect by adding this requirement to the Air Construction Permit. In all other respects, though, GREC has adequately accounted for stack emissions of PM/PM10 and provided BACT for these PSD pollutants. As noted in the Technical Evaluation, GREC has provided BACT through the superior combustion of a BFBB, baghouse, DSI, and SCR, as well through the control of SO2 and NOX and visible emissions. GREC's stack emissions of PM10 do not exceed the NSPS limit for this pollutant. Although GREC's stack emissions of PM10 require more elaborate PSD analysis due to their exceeding the PSD significant impact level for PM10, GREC's modeling supports a finding that the these impacts will be highly localized-- restricted to the GREC/GRU site, mostly along the south fenceline--and will require no ambient air quality sampling due to the sampling program already in existence in Alachua County. GREC's modeling also supports findings that the impacts of GREC's stack emissions of PM10, when combined with the air quality impacts from all sources, will be substantially below the 24-hour and annual PSD Class II increments and national AAQS, so the GREC facility will not cause or contribute to an exceedance of the PM10 PSD increments or national AAQS. Fugitive Emissions of PM/PM10 Petitioners claim that the draft Air Construction Permit inadequately accounts for fugitive emissions from the wood piles and biomass handling of PM and PM10. The preceding analysis included all of GREC's PM10 emissions--stack and fugitive. The draft BMP plan and other design elements adequately account for fugitive emissions of PM/PM10, and the procedures described in the BMPs plan and other design elements constitute BACT. Spontaneous Combustion of Wood Piles and PM Emissions Petitioner claims that the draft Air Construction Permit fails to adequately protect against spontaneous combustion and the PM emissions that would result from a fire. The wood piles present a risk of fire from spontaneous combustion. Microbial metabolic action within the pile can generate sufficient heat to cause the wood pile to combust. The primary safeguard against this risk is proper fuel management to minimize the heat buildup within the pile. One way to manage the fuel for fire safety is to mix the wood piles to aerate the piles and prevent hot spots. Another way to manage the fuel is to ensure that the fuel is not allowed to remain in the pile too long. GREC's first-fuel-in, first-fuel-out policy limits the age of any part of the wood pile. The implementation of this policy is further assured by the fact that the fuel loses heat value over time, so GREC will gain more burn for the dollar by combusting the fuel sooner, rather than later. The ratio of stored fuel to combustion rates suggests that all fuel will be turned over within 20 days--probably sooner, after the late revision lowering the height of the automatic stacker/reclaimer pile by 25 feet. Anecdotal evidence suggests that 20 days' residence in the wood pile is well short of the age of fuel that has spontaneously combusted in piles in the past. The stormwater management system will also enhance fire safety by draining rainwater and runoff from the piles and discouraging the ongoing saturation of the fuel piles. Excessive, intermittent saturation of the pile may encourage the microbial activity that can lead to combustion. As part of the local review that took place for the GREC facility, Gainesville Fire Department representatives met three times with GREC representatives to address fire safety, as the Development Review Board of the City of Gainesville reviewed the GREC proposal. As a result of these meetings, GREC agreed to a number of changes to assure substantial compliance with the National Fire Protection Association (NFPA) standards for the management of wood storage areas. As noted above, one change after consultations with the fire department was to reduce the automatic stacker/reclaimer pile from 85 feet to 60 feet. This reduces the risk of fire by making it easier to mix the entire pile and reduces the volume of fuel stored onsite and, thus, the time that that the fuel may remain unused in the wood pile. Secondarily, this change also reduces the volume of fuel available to burn in an unintended fire. To conform to NFPA standards, GREC also agreed to place low barrier walls between the fuel piles; to drive stakes around the perimeter of the piles, so inspectors could more easily check that the piles are not migrating or expanding; and to insert temperature probes into the piles to allow timely detection and elimination of hot spots that might otherwise develop into fires. A revised site plan, as reflected in Exhibits 50A, 50B, and 50C, incorporates the barrier walls and perimeter stakes identified above, as well as the layout of the fire main and fire hydrants that loop the fuel storage area and some access issues for firefighting equipment, which may weigh as much as 30 tons. After DEP adds to the Air Construction Permit the changes to the above-described changes to the site plan, which do not relocate emissions units so as to require remodeling emissions, GREC has provided reasonable assurance that the draft Air Construction Permit adequately protects against spontaneous combustion and the PM emissions that would result from a fire. Failure To Assure Uncontaminated Supplies of Biomass Petitioner claims that the draft Air Construction Permit fails to adequately assure that the biomass fuel will be free from contaminants prior to its combustion in the BFBB. Draft Air Construction Permit Section 3.A.6 requires clean woody biomass, and the draft BMP plan addresses the means to ensure that only clean woody biomass is burned in the BFBB. Suppliers must perform most of the processing offsite; for each shipment, GREC must record the date, quantity, and description of the material received; GREC must inspect each shipment for nonconforming materials; GREC must reject or segregate nonconforming material, if it is discovered; and GREC must maintain records of rejected shipments and their disposition. At the hearing, GREC agreed to another prohibition--namely, that it may not burn construction and demolition debris. GREC has provided reasonable assurance that only clean woody biomass will be combusted at the GREC facility.
Recommendation It is RECOMMENDED that, subject to the additional conditions set forth in the preceding paragraph, DEP enter a final order granting the Air Construction Permit. DONE AND ENTERED this 7th day of December, 2010, in Tallahassee, Leon County, Florida. S ROBERT E. MEALE Administrative Law Judge Division of Administrative Hearings The DeSoto Building 1230 Apalachee Parkway Tallahassee, Florida 32399-3060 (850) 488-9675 SUNCOM 278-9675 Fax Filing (850) 921-6847 www.doah.state.fl.us Filed with the Clerk of the Division of Administrative Hearings This 7th day of December, 2010. COPIES FURNISHED: Lea Crandall, Agency Clerk Department of Environmental Protection Douglas Building, Mail Station 35 3900 Commonwealth Boulevard Tallahassee, Florida 32399-3000 Tom Beason, General Counsel Department of Environmental Protection Douglas Building, Mail Station 35 3900 Commonwealth Boulevard Tallahassee, Florida 32399-3000 Mimi Drew, Secretary Department of Environmental Protection Douglas Building 3900 Commonwealth Boulevard Tallahassee, Florida 32399-3000 David S. Dee, Esquire Young Van Assenderp, P.A. 225 South Adams Street Suite 200 Tallahassee, Florida 32301-1700 Mick G. Harrison, Esquire 205 North College Avenue, Suite 311 Bloomington, Indiana 47404 Jack Chisolm, Esquire Department of Environmental Protection 3900 Commonwealth Boulevard, Mail Station 35 Tallahassee, Florida 32399-3000 Raymond O. Manasco, Jr., Esquire Gainesville Regional Utilities 301 Southwest 4th Avenue Gainesville, Florida 32614 Douglas S. Roberts, Esquire Hopping Green & Sams 119 South Monroe Street Suite 300 Post Office Box 6526 Tallahassee, Florida 32301 Richard E. Condit, Esquire 1612 K Street, Northwest, Suite 1100 Washington, DC 20006
The Issue Whether the alleged violation exists and, if so, whether orders for corrective action should be made final against respondents or either of them?
Findings Of Fact On October 17, 1984, Sunshine acquired from R & F what had been a filling station at the corner of U.S. Highway 98 and Laurie Avenue in Bay County, Florida. The old gas pumps had been moved some time before October 17, 1984. Only loose pipe connections leading to the underground storage tanks remained. The deed K & F executed in favor of Sunshine made no mention of these tanks. Respondent's Exhibit No. 1. Sunshine later contracted with Jake Walters, who began construction the following April to convert the site into a convenience store with gas pumps. On January 25, 1985, long before bringing any petroleum product onto the property, Jake Walters' construction foreman, John Kenneth Barnes, began taking up the two-foot slab of concrete that overlay K & F's underground storage tanks. The ground underneath the concrete smelled of gasoline. James Guris, who was overseeing the job for Sunshine, ordered work stopped and told Harold Millis, Sunshine's vice-president for real estate and construction, about the feel and smell of the soil. When Mr. Millis learned of the situation, he decided that DER should be notified. Because by then it was too late in the day to reach DER, Jim Guris called DER's office in Panama City on the following Monday, January 28, 1985. He spoke to DER's Grady Swann, who told him to file a discharge notification form with DER. Mr. Swann said removal of the underground tanks could go forward. Before removing the storage tanks, Mr. Barnes, or somebody at his direction, measured the depth of the tanks with a stick to determine how deep to dig. In this way two or three inches of gasoline were discovered in the bottom of each tank. Even though workmen secured a pump and pumped gasoline from each underground tank (into a 500-gallon tank mounted on a truck), they were unable to pump the tanks completely dry. In each of the three underground tanks, about a half inch of gasoline remained. With a crane and lifting rigs, they raised the tanks in an upright position, without spilling any gasoline. Except inside where the half inch of gasoline stood, the tanks and appurtenant pipes and tubing were dry. Mr. Guris ordered pressure tests done on the tanks, each a cylinder some five feet in diameter. Two of the tanks passed this test, but the third failed. That tank had a hole approximately one quarter inch in diameter a little left of center, about half way up one end of the tank. Groundwater on the site came within four and a half or five feet of the surface in early February of 1985. Because it contains less than 10,000 parts per million total dissolved solids, it is properly classified as G-II. A marine clay separates the surficial aquifer from the Floridan, but the surficial aquifer recharges the Floridan. Northeast of where the storage tanks were dug up and 300 to 350 feet way a two-inch well 390 feet deep supplies water from the Floridan aquifer to three households. Nobody has detected any odor or taste of gasoline in water from those wells. Grady Swann took soil samples on site on February 8 and again on February 26, 1985. On his first visit, he noticed no sheen on the surface of the water standing in the area excavated around the old tanks, smelled no odor emanating from the standing water and did not take a sample. On his second visit, he did notice evidence of groundwater contamination and took water as well as soil samples. Mr. Swann returned on March 11, 1986, with Kenneth L. Busen and Mike Wilson of DER's Operation Response Team and used a power augur to put in temporary wells from which additional water samples were taken. These tests confirmed suspicions that the old gas tanks had leaked and revealed groundwater contamination attributable to gasoline including, in some samples, more than 1,000 times the allowable concentration of benzene. Gasoline seeping through soil leaves residual hydrocarbons which contaminate percolating rain or other groundwater moving through the same soil. Petitioner's Exhibit No. 6 depicts the probable initial configuration of the plume of hydrocarbons in the vicinity of the old tanks. Contamination is moving down gradient to the northeast, spreading out but growing more dilute. The steps called for by the proposed corrective orders are a reasonable way to mitigate environmental damage.
Findings Of Fact The petitioner is a non-profit corporation consisting of individual members who are residents of Tallahassee and Leon County and organizational members who have chapters in Tallahassee and Leon County. The primary purpose of petitioner is to bring about a balanced transportation system in Tallahassee and Leon County taking into consideration certain criteria which include the following: the prevention of neighborhood disruption and deterioration; the prevention of environmental degradation; and the prevention of harm to historical sites. In conjunction with this purpose and these criteria, one of petitioner's primary concerns is the prevention of degradation of air quality in the Tallahassee, Leon County area. Some members of the petitioner use that part of Thomasville Road to be affected by the subject application. The project for which the Department of Transportation seeks a Complex Source Permit is the four-laning of Thomasville Road from Eighth Avenue to Interstate 10 in Tallahassee, Florida. The Complex Source Permit was originally submitted to the Department of Environmental Regulation on March 22, 1976. The Department of Environmental Regulation did not accept that application, however, due to unacceptable modeling and monitoring. Thereafter, two supplements to the application were submitted to the Department of Environmental Regulation. The first, dated September 21, 1976, and the second, dated November 16, 1976, contained additional monitoring and a repeat of the modeling effort. Because of allegedly incorrect counts and speeds, the Department of Transportation submitted yet another application with revised monitoring and modeling data on January 4, 1978. This latest revised application is the subject of this hearing. The Department of Transportation did not monitor for or project the concentrations of any pollutant listed in Section 17-2.05, F.A.C., except carbon monoxide. The Department of Environmental Regulation did not require the monitoring for or projection of concentrations of any pollutant listed in Section 17-2.05, F.A.C., except carbon monoxide. The evidence presented in this proceeding does not establish that construction of the project for which a Complex Source Permit is sought herein would result in or cause an increase in ambient pollutant concentrations of any pollutant listed in Section 17-2.05, F.A.C., with the exception of carbon monoxide. The evidence presented indicates that remaining pollutants listed in the foregoing section would be emitted in insignificant quantities having no effect on the ambient air quality standard for that pollutant. The Department of Environmental Regulation has not independently monitored for any of the pollutants considered by Section 17-2.04(8), F.A.C., but has relied entirely on data submitted by the Department of Transportation. The Department of Transportation has based its carbon monoxide projections upon the use of the California Line Source Model, also known as Calair I, which is a mathematical computer model. It appears from the evidence presented that the Calair I computer model was used in a reasonable and proper manner and produced data which could be relied upon by the Department of Environmental Regulation. The Complex Source Permit application as finally submitted on January 4, 1978, projects the following concentrations for carbon monoxide: one-hour concentration for 1979, 6.7 ppm and for 1939, 4.8 ppm; for eight-hour concentrations in 1969, 2.8 ppm and for 1989, 2.0 ppm. The ambient air quality standard for carbon monoxide set forth in Section 17-2.05(1)(c), F.A.C., is 9 ppm maximum eight-hour concentration and 35 ppm maximum one-hour concentration, both not to be exceeded more than once per year. The testimony indicates that even if the calibration factor with the Calair I model were doubled, the projected carbon monoxide concentrations would not exceed the foregoing standard. No evidence was presented on the issues initially raised in this proceeding involving the Major Thoroughfare Plan, the Transportation Improvement Plan, and the Urban Area Transportation Plan. The testimony and evidence presented in this proceeding establishes reasonable assurance that the subject project will not cause a violation of the ambient air quality standards for the major pollutants to be emitted.
The Issue The issue in this case is whether Respondent, Action Instant Concrete, LLC (AIC), should be allowed to use the Concrete Batching Plant Air General Permit promulgated by Respondent, Department of Environmental Protection (DEP), in Florida Administrative Code Rule 62-210.300(4)(c)2.1
Findings Of Fact Petitioners, Paul and Barbara Corbiey, live at 7380 Southwest 86th Lane, Ocala, Florida, in an area called Green Turf Acres. Petitioners' property shares a boundary with property owned by AIC at State Road 200. In 2003 AIC began construction of a relatively small cement silo and area for storage of rock aggregate and sand to mix with the cement, similar to facilities at a related operation some distance away. The other operation is within the jurisdiction of DEP's Central District, which did not require a permit for the operation. AIC's operation in Ocala is in DEP's Southwest District, which is headquartered in Tampa. Periodically (and irregularly but apparently usually early in the morning) AIC receives deliveries of cement to the silo at its facility next to the Corbieys. The silo is essentially a rectangular bin with a baghouse, essentially another rectangular structure attached to the silo and containing a combination of filters. Deliveries are made using an enclosed truck with a blower and flexible hose that can be positioned and attached to the fill spot on the silo. The transfer of cement from truck to silo is accomplished pneumatically, with the air exhausted through the baghouse, which is designed to capture and retain cement particles within the silo as the air passes through to the outside of the silo. If there are particulate emissions during the process, they typically would come from the baghouse. AIC also has aggregate and sand delivered to storage areas on either side of the silo. Each of the storage areas has walls made of 4-5 courses of cement block on three sides. The walls are there mainly to contain the aggregate and sand but also serve as a partial windbreak. During AIC's operations, trucks come to pick up cement, aggregate, and sand. To load cement onto the trucks, cement is gravity-fed from a hopper on the silo, through a flexible tube, and into the truck; aggregate and sand also are loaded into trucks using a front-end loader. Unconfined emissions can and, at least sometimes, do occur during the loading processes. After loading, the trucks are driven offsite, typically to a construction site, where the cement, aggregate, and sand are batched to form concrete. When AIC began operations, its yard was covered with grass and weeds, which helped suppress fugitive dust when trucks drove in and out. Later, the grass and weeds died, and AIC installed three sprinkler heads to keep the area watered to help suppress fugitive dust. When AIC began construction and operation, Petitioners complained to numerous authorities that AIC's construction and operation were illegal, inappropriate, and should not be allowed for various reasons, including alleged particulate emissions and fugitive dust that was harmful to the health and property of Petitioners and their neighbors.13 One complaint was lodged with DEP's Central District, which referred it to DEP's Southwest District. DEP's Southwest District investigated, determined that AIC should have obtained a permit, initiated compliance action, and required AIC to make use of the Concrete Batching Plant Air General Permit promulgated by DEP in Rule 62- 210.300(4)(c)2. DEP also fined AIC in the amount of $4,150, plus $100 to reimburse DEP for its costs, for constructing and operating without a permit.14 These amounts were paid. It does not appear from the evidence in the record that DEP ordered AIC to cease operations until DEP allowed AIC to use the Concrete Batching Plant Air General Permit. It does not appear that AIC ceased operations. As DEP instructed, AIC had a VE test performed in accordance with EPA Method 9 for submission with a Concrete Batching Plant Air General Permit Notification Form, fee, and proof of public notice. AIC retained Koogler & Associates for this purpose, and the test was performed on April 26, 2005. On April 29, 2005, AIC published notice in the Ocala Star-Banner that it intended to use the Concrete Batching Plant Air General Permit. On May 5, 2005, Koogler & Associates prepared a VE Observations Report for AIC. On May 16, 2005, Petitioners filed a Petition opposing AIC's use of the Concrete Batching Plant Air General Permit and seeking its revocation. On May 19, 2005, AIC submitted a Concrete Batching Plant Air General Permit Notification Form, fee, proof of public notice, and VE observation report to DEP. At the hearing, John B. Koogler, Ph.D., P.E., an expert in environmental science and air quality, and the principal of Koogler & Associates, testified as to the cement and concrete industry in general, EPA Method 9, required certifications for conducting a VE test under EPA Method 9, VE testing under EPA Method 9, and the VE Observations Report prepared for AIC by Koogler & Associates. In the case of AIC's operation, VE testing measures stack emissions during standard loading of cement under pressure. Typically, if there are emissions during the process, they will be seen at the baghouse on the silo--i.e., the dust collector at the exhaust point. This is where VE is measured during testing. AIC's stack emissions were tested at a loading rate of approximately 50 tons per hour; at that rate, 25 tons of cement were loaded into the silo in half an hour. According to AIC's VE Observations Report, there were no stack emissions during testing. Dr. Koogler did not perform the test himself and did not sign the Observations Report, but the test was performed and the report was prepared under his general supervision, and experts in his field routinely rely on VE testing performed by certified technicians under general supervision and on observations reports prepared by others under general supervision. According to Dr. Koogler, the test for AIC appeared to have been performed properly and met the requirements of EPA Method 9 and DEP's statutes and rules for use of the Concrete Batching Plant Air General Permit. Petitioners questioned the veracity of the VE Observations Report, primarily by speculating that the certified technician who performed the test may have fabricated the observations, either with or without his employer's knowledge. This speculation is rejected as unfounded. Petitioners also repeatedly questioned the consistent and reasonable testimony of all the experts that valid, authorized VE observations could not be performed using Petitioners' videotapes. Besides, the videotape in evidence did not show loading of the silo. As a result, Petitioners presented no evidence that VE in excess of five percent opacity occurred during cement loading of the silo. Petitioners also alleged that violations occurred during the loading of trucks at AIC's operation. Witnesses testified to seeing various amounts of dust from various distances occurring at various times, but their testimony was not specific. Parts of the videotape in evidence show some unconfined emissions occurring during the loading of at least some of the trucks. However, as indicated above, VE testing is not done for unconfined emissions; in addition, standardized opacity measurements could not have been made from a videotape. Finally, the videotape showed that AIC uses a chute, or partial enclosure, to mitigate emissions at the drop point to the truck, and the evidence was that AIC maintains its parking areas and yards and applies water when necessary to control emissions. Cf. Conclusions 22-23, infra. Dr. Koogler also opined that AIC and its operation may use the Concrete Batching Plant Air General Permit under a proper interpretation of the statutes and rules, in particular Rule 62-296.414, which states that it not only applies to "emissions units producing concrete and concrete products by batching or mixing cement and other materials" but also applies to "facilities processing cement and other materials for the purposes of producing concrete." This opinion was consistent with DEP's interpretation of the statutes and rules. Petitioners also contended that AIC was ineligible for the Concrete Batching Plant Air General Permit because its facility already was in existence and was operating without a permit. However, expert witnesses for DEP and for AIC testified consistently and reasonably that DEP can require a facility operating without a permit to use the Concrete Batching Plant Air General Permit in order to come into compliance. It is not necessary for the facility to dismantle its facility and rebuild after obtaining authorization to use the Concrete Batching Plant Air General Permit under Rule 62-210.300(4)(a)2. Under these circumstances, it is reasonable for the facility to submit VE test results along with the facility's initial Concrete Batching Plant Air General Permit Notification Form, fee, and proof of public notice. In the exercise of its discretion to enforce compliance, DEP allowed AIC to continue to operate before and during the pendency of this proceeding. Petitioners questioned the wisdom and propriety of this choice, but DEP's exercise of discretion in enforcing compliance is not at issue in this proceeding. See Conclusion 24, infra.
Recommendation Based upon the foregoing Findings of Fact and Conclusions of Law, it is RECOMMENDED that DEP enter a final order approving AIC's use of the Concrete Batching Plant Air General Permit under Rule 62-210.300(4)(a)2. Jurisdiction is retained to consider a motion for costs and attorney fees under Section 57.105, Florida Statutes, if filed within 30 days after issuance of the final order. DONE AND ENTERED this 31st day of March, 2006, in Tallahassee, Leon County, Florida. S J. LAWRENCE JOHNSTON Administrative Law Judge Division of Administrative Hearings The DeSoto Building 1230 Apalachee Parkway Tallahassee, Florida 32399-3060 (850) 488-9675 SUNCOM 278-9675 Fax Filing (850) 921-6847 www.doah.state.fl.us Filed with the Clerk of the Division of Administrative Hearings this 31st day of March, 2006.
Findings Of Fact DER is the agency that has been charged by statute with the responsibility of administering programs to advance the legislative policy to preserve and protect air quality. Chapter 403, Florida Statutes (1977). DER has adopted what is commonly called its "Complex Air Source Rule". The Rule has been codified in Chapter 17-2, Florida Administrative Code. A copy of Chapter 17-2 was received into evidence at the hearing. The Complex Air Source Rule requires that a permit be obtained before certain potential sources of air pollution are constructed or operated. An applicant for a permit is required to provide reasonable - assurances that the proposed project will not violate DER's air quality standards. The rule establishes air quality standards for the following pollutants: sulphur dioxide, particulate matter, carbon monoxide, photochemical oxidants, hydrocarbons, and nitrogen dioxide. The Petitioners own property along Gulf Boulevard in Treasure Island, Pinellas County, Florida. The Department of Transportation has applied to DER for a complex air source permit to engage in a road widening project along Gulf Boulevard. Petitioners are parties to an administrative proceeding currently pending before the Division of Administrative Hearings. The issue in that proceeding is whether DER should grant the Department of Transportation the requested permit. The parties have stipulated that the Petitioners have standing to maintain the instant action. In its Motion to Intervene the Jacksonville Transport tation Authority alleged that it is proposing construction of an expressway system in Duval County, Florida. The Intervenor alleges that it will need to obtain a complex source permit from DER in order to engage in the construction. The Intervenor presented no evidence respecting these allegations at the hearing. DER's rule 17-2.05(3), Florida Administrative Code, provides for complex air source permits. A "complex source" is defined in Rule 17- 2.05(8)(a)(1) as follows: Any facility or group of facilities, which is a source of air pollution by reason that it causes, directly or indirectly, significant increases or emissions of pollutants into the atmosphere or which reasonably can be expected to cause an increase in the ambient air concentrations of pollutants, either by itself or in association with mobile sources. Roadways and widened roadways constitute complex sources under the definition. Permits must be obtained from DER before new roads, or road modifications can be constructed. Rule 17-2.05(8)(c) 3-5. Rule 17-2.05(8)(b) provides: No person shall construct or modify or operate or maintain any complex source of air pollution which results in or causes an increase in ambient pollutant concentrations in violation of the ambient air quality standards. DER may not issue a complex air source permit unless it is reasonably assured that the proposed project will not violate the ambient air quality standards set out in Rule 17-2.06, and in Table 3 thereof. The applicant is required to submit such information as DER requires to make its determination. Rule 17- 2.05(8)(d) provides: Any person seeking a permit shall submit such information that is necessary for the Department to determine that the complex source will not cause a violation of Ambient Air Quality Standards and submit to the Department such information that shall include, but not be limited to: The nature and amounts of pollutants to be emitted or caused to be emitted by the complex source, or by associated mobile sources, and an air quality impact statement. The location, design, construction and operation of such facility. The Petitioners contend that DER has a practice of requiring applicants for complex source permits to submit information, and to provide the requisite reasonable assurances only with respect to projected emissions of carbon monoxide. It is alleged that DER does not require applicants to submit data respecting other pollutants, or to provide any reasonable assurances with respect to the other pollutants described in DER's Ambient Air Quality Standards. It is further alleged that DER evaluates only expected emissions of carbon monoxide when evaluating an application for a complex air source permit. These allegations are not supported by the evidence. DER has a policy of requiring applicants for complex air source permits to submit in the initial application only data respecting projected carbon monoxide emissions. With respect to automobile related pollutants, carbon monoxide is known as a controlling pollutant. Automobile related pollutants essentially are carbon monoxide, hydrocarbons, and nitrogen oxides. A decrease of carbon monoxide emissions causes a greater decrease in hydrocarbon emissions. A decrease in carbon monoxide emissions causes a decrease of nitrogen oxide emissions at a slightly reduced percentage. Changes in ambient levels of these related pollutants can be predicted by considering carbon monoxide data. Furthermore, high concentrations of carbon monoxide are a localized problem. High carbon monoxide readings generally reflect one or just a few sources of carbon monoxide emissions within a localized area. High readings of hydrocarbons, nitrogen dioxide, and photochemical oxidants, on the other hand, are not localized, but rather reflect a number of pollutant emitting activities over a broad area. DER has established monitoring stations, where concentrations of pollutants are measured. Data obtained from these stations is utilized to provide DER with information as to areas that experience high concentrations of hydrocarbons, nitrogen oxides, and photochemical oxidants. When a project is proposed in such an area, DER requires applicants to submit ad ditional data respecting projected emissions of these pollutants that would result from the project. Such additional data has been requested by the Department in several cases. Where there is no indication that concentrations of these pollutants are occuring in an area, DER is able factually to assure itself that a given project will not result in violations of the standards respecting these pollutants by considering the carbon monoxide data. It is for this reason that applicants are not initially required to submit data respecting pollutants other than carbon monoxide. DER is able to assure itself that roadway projects will have no impact upon concentrations of sulphur dioxide and particulate matter because these are not pollutants that are associated with automobiles. DER's policy of not requiring applicants to submit data respecting pollutants other than carbon monoxide does not relieve an applicant of its duty to provide information necessary for DER to determine that the proposed project will not cause violations of any of the ambient air quality standards. The Department utilizes its own data in making such determinations, and if a project is proposed in an area where there are high concentrations of pollutants other than carbon monoxide, DER requires the submission of further data. DER's practices and Policies are thus not contrary to its rules, and the practices and policies do not constitute rule making.
The Issue The issues are (1) whether engaging in air conditioning contracting regulated by the Florida Electrical Contractors Licensing Board pursuant to Section 489.500 et seq. Part II, Florida Statutes, constitutes exceeding the scope of one's license as an electrical contractor, (2) whether performing air conditioning contracting in the name of "Dixon's Heating and Air Conditioning" constitutes operating in a name other than the name his electrical contracting license is issued in, contrary to Subsection 489.533(1)(l), and (3) whether Respondent willfully violated the building codes by venting the heater improperly, failing to get a permit and get work inspected.
Findings Of Fact Notice of hearing was given to Respondent at Route 2, Box 595, Yulee, Florida 32097. Arnold Dixon is and has been at all times material to this case a registered electrical contractor, license number ER0004417. (Pet. Ex. 1 & 2) He has maintained his address of record as Route 2, Box 595, Yulee, Florida 32097. (T-Pg. 6) He has held such license since 1976. (Pet. Ex. 1 & 2) Arnold Dixon does not hold a license, a state registration or certification to engage in contracting as a heating or air conditioning contractor. (Pet. Ex. 4 & 6) Arnold Dixon does hold a Nassau County Occupational License as an electrical contractor and as a heating and air conditioning contractor. No check of local records was conducted to see if he had a local license as an air conditioning contractor. (T-Pg. 22) On or about June 1985, the Respondent's company, Dixon's Heating and Air Conditioning, contracted to install an air conditioning and heating unit at the home of John Williams for a contract price of $1985. (Pet. Ex. 5 and T-Pgs. 10 & 11) The work on this contract was done by David Everett, who negotiated the contract. The Respondent's company, Dixon's Heating and Air Conditioning, did not obtain a permit to perform the work at the Williams' residence. Inspections on the Williams' job were not called for by Dixon's Heating and Air Conditioning. Permits and inspections were required by the applicable building code. (T-Pgs. 25 & 26) Entering into a contract to perform air conditioning and heating work and performing such work is air conditioning contracting, which is regulated under Part I, Chapter 489, Florida Statutes. After installation by Dixon's Hearing and Air Conditioning, the Williams' heating system generated carbon monoxide when operating because there was insufficient fresh air being provided to the unit. Because the air intake was in a closet which restricted the air supply to the hot air handling system, the air handling unit sucked fumes from the exhaust side of the unit back through the unit's combustion chamber and circulated it through the house. The longer the unit ran, the more debris was trapped in the louvered door of the closet and the more combustion gases were pulled through the combustion chamber and distributed through the house by the air handling unit. (T-Pg. 34) According to the manufacturer's representative, the hot air return is required to be ducted into the unit. In this case, the return air was pulled from inside a closet which had louvered doors. No duct was used and this installation was not in accordance with the manufacturer's instructions. Although the unit as installed was unsafe and had the potential to kill, no evidence was received that failure to install the unit in accordance with the manufacturer's instructions was a violation of local building code. (T-Pgs. 34- 38) Dixon's Heating and Air Conditioning did not hold itself out to be and was not engaged in electrical contracting in fulfilling the Williams' contract. Dixon's Heating and Air Conditioning did hold itself out to be an air conditioning contractor and the work performed in fulfilling the Williams' contract was air conditioning contracting.
Findings Of Fact PROPOSED FACILITY The applicant, FRI, plans to construct a Portland cement plant (the plant) at its existing quarry located off Alachua County Road 235, 2.5 miles northeast of Newberry, Florida. The plant site consists of 46 acres located near the center of more than 1,300 acres of limestone and overburden reserves. Portland cement is a material used to construct common items such as buildings, roads and pipelines. The necessary raw ingredients include sand, clay and limestone. Eighty percent of the raw feed material is limestone. The project includes a single kiln, clinker cooler, preheater, precalciner, crusher, raw mill, finish mill, silos, conveyors, and an assortment of equipment for particulate control/dust collection, cement and clinker handling, coal handling, air pollution control, and recycling. The proposed plant has seven emission units. The first emission unit is related to the mining and storage of raw materials. Limestone, sand and clay are sized and mixed at the quarry according to standards set by the American Society of Testing Materials (ASTM). Next, conveyors transport the raw material to a covered storage area. The second emission unit is the raw material grinding and blending unit. In the covered storage area, the plant operator further blends the raw feed material with other secondary materials, including coal ash. This unit contains an auxiliary heater which uses number two fuel oil and a roller mill where the material is ground. The raw material arrives at the second emission unit containing eight to ten percent moisture content to prevent the generation of dust. The auxiliary heater removes this moisture and dries the raw feed material. This step is necessary because the proposed facility is a dry process cement plant as opposed to a wet process cement plant. In the former, the feed material is dry when it enters the kiln. In the later, the feed material is a wet slurry. Emission unit three includes the preheater, precalciner, and kiln. The raw material proceeds from the grinder to the preheater where it is preheated as it falls vertically downward through exhaust gases rising upward from the kiln. Next, the feed material passes through the precalciner where fuel is added to calcine the feed material before it reaches the kiln. The calcining process involves the decomposition through heat of limestone (calcium carbonate) to lime (calcium oxide) and carbon dioxide. About sixty percent of the kiln system's fuel is fed into the precalciner. FRI may use tires as an alternate fuel. Tires are fed into the kiln system at the transition section between the base of the precalciner and the point where gases exit the kiln. As described in the record the tire feeder mechanism has a double airlock, vertical and horizontal guillotine gates, and a ram. The permitted feed rate for tires is thirty percent of the total heat input or approximately 400 tires per hour. After passing through the precalciner, the feed material passes into the raised end of the kiln to produce clinker. The kiln is an inclined rotating cylinder, approximately twelve feet in diameter and one hundred sixty-two feet long. FRI plans to feed fuel into the lower end of the kiln where it discharges the clinker. To produce clinker, the kiln must heat the feed material to a temperature of approximately 2700 degrees Fahrenheit. The gases in the subject kiln will reach temperatures between 3700 to 3800 degrees Fahrenheit. Emission unit four is the clinker cooler, belt transfer and two clinker silos. The clinker exits the kiln at temperatures in excess of 2,000 degrees Fahrenheit. The clinker then falls into the clinker cooler where ambient air is passed through the clinker to cool it. In the cooling process, the air becomes heated. The plant uses this hot air as combustion air in the kiln and heating air for the coal mill. A conveyor transfers the cooled clinker to two silos. The finish mill and cement storage silos are emission unit five. The plant transfers clinker from the silos to the finish mill (or roller mill) where the plant operator adds gypsum and/or limestone as required by ASTM standards. Next, the plant transports the finished cement to the cement storage silos. Emission unit six consists of cement handling and packaging operations. FRI plans to ship the finished product in bags or in bulk by rail or truck. Emission unit seven consists of coal handling operations. The plant receives coal on site by rail and stores it in a covered storage area. The plant grinds the coal in a grinder which is heated by hot gases from the clinker cooler. After being ground, the plant transfers the coal to a small storage silo and feeds it into the kiln and precalciner. The proposed plant has the capacity to produce 2300 tons of clinker per day. It will, on average, produce 712,500 tons of clinker per year. The plant will yield approximately 772,400 tons of Portland cement per year. BACT ESTIMATES, PROPOSALS, AND LIMITATIONS Best available control technology (BACT) is an emission limitation determination made on a case-by-case basis taking into account several factors including energy, environmental and economic impacts and other costs. Petitioner failed to present any persuasive evidence regarding the inadequacy any of the BACT factors listed in Rule 62-212.400(5) and (6), Florida Administrative Code. BACT for a particular source evolves and becomes more stringent over time as technology evolves. A regulating agency uses BACT to force applicants to develop technology which will optimize processes and improve emission rates. The plant will be a major emitting facility for certain regulated pollutants: particulate matter (PM and PM10), sulfur dioxide (SO2), nitrogen oxides (NOx), and carbon monoxide (CO). The project site is located in an area which has been designated attainment for all criteria pollutants. The proposed facility is subject to the Prevention of Significant Deterioration (PSD) regulations because the potential emission of each of the above referenced pollutants exceeds one hundred tons per year. PSD review consists of a determination of BACT and an air quality impact analysis for each of these regulated pollutants. The Department performed a BACT determination for emissions of SO2, NOx, PM/PM10, CO, VOCs and beryllium because the emissions of these six pollutants are at levels in excess of PSD Significant Emission Rates. Petitioner only challenges the BACT determination for SO2 emissions limits. However, Petitioner challenged the design of the proposed plant and the sufficiency of the control mechanisms to provide reasonable assurances that FRI will not meet BACT emission limits. CARBON MONOXIDE The BACT emission rate for CO is 3.6 pounds per ton of clinker or 346.38 pounds per hour. FRI has provided reasonable assurances that this limit will be met through process controls and the use of continuous emissions and process monitors. NITROGEN OXIDES The BACT emission rate for NOx is 2.8 pounds per ton of clinker after an initial limit for two years of 3.8 pounds per ton of clinker. The interim limit is necessary to allow for an optimization period in which FRI can comply with the 2.8 pounds per ton limit. The Department may revise the limit to less than 2.8 pounds per ton of clinker based on compliance tests and continuous emission monitoring data. The Department determined the NOx BACT emission limit in part after considering a California cement plant's NOx BACT emission limit of 2.5 pounds per ton of clinker and then normalizing the number for the FRI plant. FRI's feed material is wetter than the feed material at the California plant. Therefore, FRI will require more coal to dry the feed. The increased consumption of coal will result in higher NOx emissions. Additionally, the coal used at the California plant has greater volatility than the coal used at FRI's plant. During the two year optimization period, mechanical features of the plant will wear in and the refractory in the kiln will be cured. FRI will use the start-up time to determine the optimum oxygen levels and temperatures throughout the kiln system. The plant operator will make operational adjustments in the feed mix and the kiln rotation speed. It is not unusual for a cement plant to need approximately two years to make the operational adjustments necessary to comply with NOx emission limits. Other existing dry process cement plants meet their NOx emission limits using only one firing point. In the FRI plant, the use of two firing points (without using tires as fuel) and three firing points (using tires as fuel) will spread combustion over more locations. Spreading the combustion points will reduce the oxygen requirements thereby restricting NOx formation. Preheater type kilns burn some fuel at temperatures lower than the temperatures in the kiln burning zone. This results in NOx emissions which are lower than the emissions from a kiln without a preheater. The subject facility has a preheater and a precalciner which means that the proportion of the fuel burned at the calcining temperature is much greater than in a kiln with only a preheater. The result here will be even lower NOx emissions. Using tires as fuel will also reduce NOx emission rates because tires burn with less intense heat than coal. However, FRI will meet the NOx emission limit even if it decides not to burn tires as an alternate fuel. Therefore, a finding of reasonable assurance that the plant will meet the NOx BACT emission limit is not dependent upon FRI burning tires as fuel. The manufacturer of the kiln, Polysius Corporation, does not guarantee that the NOx emissions from the proposed facility will be below 4.0 pounds per ton of clinker. FRI stipulated at hearing that it would supply additional technology to reduce NOx emissions if the plant does not comply with the emission limit within two years. However, the greater weight of the evidence indicates that FRI will not need additional technology to meet the NOx emission limits. Therefore, the undersigned has not relied on this stipulation in finding reasonable assurances. FRI has provided reasonable assurances that the NOx emission rate will be met through process controls and the use of continuous emissions and process monitors. COMPLIANCE WITH NOx AND CO EMISSION LIMITS CO is a gas which is generated when there is inadequate oxygen in the combustion of fuel and the calcining of calcium carbonate or limestone. NOx is a gas which is a combination of oxides of nitrogen. The plant will produce NOx during the combustion process in the kiln system when nitrogen combines with oxygen. There are three specific sources of NOx: thermal NOx, fuel NOx, and feed material NOx. The generation of CO and NOx is inversely related and linked to the oxygen level that is present in the kiln system. As the oxygen level increases, the formation of NOx increases and the formation of CO decreases. Conversely, when the oxygen level decreases, the formation of NOx decreases and the formation of CO increases. FRI will meet CO and NOx emissions levels by controlling excess oxygen in the kiln to a level between one and one-half to three percent excess oxygen. FRI will use continuous oxygen process monitors to regulate the oxygen level. One such monitor will measure the oxygen content of the gases leaving the kiln where the feed material enters the kiln. Another monitor will measure the oxygen level in gases leaving the precalciner and proceeding to the preheater. FRI will use a continuous emissions monitor (CEM) to ensure compliance with NOx emission limits. A continuous CO process monitor will assist in the control of the CO content in the kiln. Expert testimony of professional engineers corroborates the Department's predicted emission rates for CO and NOx. Other information also supports the Department's BACT determination for CO and NOx. For instance, the Environmental Protection Agency's (EPA) AP-42, Fifth Edition, USEPA, Compilation of Air Pollutant Emission Factors, contains a broad spectrum of emission factors from cement plants around the country. The Department properly relied on another EPA document, Alternative Control Techniques, EPA-453/R-94-004 (3/1994) for the proposition that burning tires will reduce NOx emissions. The Department will not issue FRI an operation permit until it demonstrates compliance with CO and NOx emission limits. SULFUR DIOXIDE The interim BACT emission limit for SO2 is .28 pounds per ton of clinker or 28.82 pounds per hour. This limit is as low as the BACT emission limit imposed at any other cement plant in the country. The Department based the SO2 interim emission rate in part on the lowest number provided by the EPA, BACT Clearinghouse. In making the SO2 BACT determination, the Department correctly considered a survey of stack test data from different facilities around the country which have been in operation for three years. Because of the wide differences in fuels and raw materials at cement plants nationwide, FRI may be able to meet a lower SO2 emission rate. Accordingly, the Department may lower the SO2 emission limit before issuing FRI an operation permit. The Department will issue the final S02 emissions limit within 120 days following receipt of all tests that the permit requires. At that time, the Department will determine the final emission limit after reviewing the results of FRI's process/pollutant optimization program. The Department will publicly notice any change in the SO2 emission limit. The plant will generate SO2 during the combustion process when sulfur in the three fuels (coal, tires and number two fuel oil) reacts with oxygen. Sulfur is also present in the raw feed materials. The plant controls SO2 emissions for the most part through process design, i.e., the capacity of the feed materials in the kiln system to absorb SO2 emissions. SO2 emissions are very sensitive to the balance between alkali and sulfur in the kiln feed and operating conditions. FRI will minimize these emissions by maintaining proper ratios of sulfur and alkali in the pyroprocessing environment and by maximizing the intimate contact between raw materials and exhaust gases. Limestone contains sodium and potassium which are alkaline materials. As the feed material passes through the kiln system, the alkaline substances absorb the SO2 in a form that will not be released when it passes through the clinkering zone in the kiln. One hundred percent sulfur absorption is not possible because no absorption system is perfect. The plant's capacity to absorb SO2 emissions is in the range of ninety-five to ninety-six percent. FRI will install an SO2 CEM. The CEM will not limit SO2 emissions but it will indicate when the plant reaches the SO2 emission rate of 28.82 pounds per hour. FRI will perform annual stack tests to determine SO2 emission rate compliance. Doubling the amount of the sulfur put into the kiln system will not double the SO2 emissions. Much of the sulfur will stay in the clinker and will not be available for emissions. There is no need for a limit on the sulfur content in the coal that FRI uses as fuel. The limestone in the kiln system will absorb virtually all of the sulfur in coal at levels between one and two percent with SO2 emission levels remaining constant. SO2 emissions will not increase unless FRI uses coal with four to five percent sulfur levels. There is no known supply of coal with sulfur levels of four to five percent. The typical industrial grade coal in Florida has a sulfur content of approximately 1.2 percent. The proposed plant has sufficient capacity to absorb any possible variations of sulfur present in the fuel because of the massive amount of lime that it will process and the configuration of the air flows in the kiln system. Nevertheless, FRI agreed during the hearing to accept a specific permit condition limiting the sulfur content of the coal to 1.25 percent by weight and sulfur content of the number two fuel oil to .05 percent by weight. Additionally, using tires as fuel does not affect SO2 emission rates. The equilibrium state of the recycled cement kiln dust (CKD) will have no effect on SO2 emissions at the plant. FRI has provided reasonable assurance that it can comply with the SO2 emission limitation. VOLATILE ORGANIC COMPOUNDS The BACT emission rate for VOCs is 11.55 pounds per hour. FRI has provided reasonable assurances that this emission limitation will be met through process controls and the use of continuous emissions and process monitors. The Department correctly based its BACT determination for VOCs in part on data received from the EPA BACT Clearinghouse. VOCs are gaseous organic compounds which include a broad range of compounds in a gaseous form at room temperature. Incomplete combustion of fuel and organic material in the feed material to the kiln system generate VOCs. Limestone contains very low levels of organic material; therefore, cement plant kiln systems produce very low levels of VOCs. FRI will reduce the VOC emissions by controlling the temperatures in the kiln system. In the kiln, the feed material will reach about 2,700 degrees Fahrenheit. The temperature of the gases in the kiln will reach between 3,700 and 3,800 degrees Fahrenheit. The temperature in the precalciner will range from 2,000 to 2,100 degrees Fahrenheit. At these high temperatures, virtually all VOCs will be consumed or destroyed regardless of their source (limestone, coal, tires, and fuel oil). Clinker production requires certain temperatures, residence time, and turbulence within the kiln. These factors are sufficient to ensure the destruction of almost all VOCs at cement plants. PARTICULATE MATTER PM is small, finely-divided solid particles. PM is not a particular compound or chemical. It is a solid form of whatever material might be present. PM10, a subset of "total" PM, refers to particulate matter that is ten micrometers in diameter or less. For the kiln, the Department set the BACT emission limit for PM and PM10 at .31 and .26 pounds per ton of clinker respectively. For the clinker cooler, the Department determined that the BACT emission limit for PM and PM10 was .16 and .13 pounds per ton of clinker respectively. In making its PM/PM10 BACT determinations, the Department correctly considered data from EPA's AP-42 and the more stringent emission rates of other kilns in Florida. The standard reference work, Air Pollution Engineering Manual, Air and Waste Management Association (1992), provides further assurance that FRI will meet the PM/PM10 limitations set forth in the permit. FRI has provided reasonable assurances that the plant will comply with the emission limitations for PM and PM10 through the use of electrostatic precipitators (ESPs) as BACT to control major sources of controlled PM. Baghouses will control other minor sources of PM. The three most recent BACT determinations nationwide for cement plant kiln systems were met with ESPs. In this case, the gas stream for the clinker cooler and the gas stream from the kiln system will vent to two ESPs for PM control. PM is controlled in an ESP by first conditioning the gas stream entering the ESP. The gas stream then passes through an area of extremely high voltage differential (tens of thousands of volts at very low amperage) where the particles develop an electrical charge. As the charged particles pass through the ESP, they are collected on a plate of opposite charge. This plate is periodically rapped to dislodge the PM into a hopper for reuse in the kiln as raw material. A vender will supply the ESPs sized to meet the PM emission limits of the plant according to the design specifications and the engineering features which are contained in the record. The facility-specific ESP engineering features include gas flow rate, volume of gas passing through the ESP, the temperature of the air stream (stack gas), the moisture content of the air stream, the nature of the particles (including resistivity), and most importantly, the ultimate PM/PM10 limitations imposed in the permit. Polysius Corporation will estimate the concentration of dust approaching the ESP and supply that information to the vendors as a separate piece of information. The plant's ESPs will have a design specification of 99.9 percent control efficiency. This control efficiency is consistent with demonstrated efficiencies in standard reference works. The specifications also require a manufacturer's guarantee of .01 grams per actual cubic feet per minute (ACFM) for outlet dust concentration. FRI proposes to operate the kiln system in two alternative modes. The first proposal routes the gas stream from the preheater through a quench tower directly to a precipitator. The second proposal routes the gas stream through the raw mill to dry the feed material and then directly to the precipitator. The PM loadings and the nature of the PM will change under each of these two sets of conditions. It is not ordinary or necessary for an applicant to submit detailed engineering drawings of ESPs with an application. The evidence is overwhelming that ESPs built to the specifications contained in the record will meet the required PM/PM10 emission limits. The type of fuel will not affect the PM emission rate. The use of tires as supplementary fuel will not cause an increase in PM emissions. To the contrary, the firing of coal and tires together reduces PM emissions. Metal emissions will not clog an ESP. FRI intends to recycle 100 percent of its cement kiln dust (CKD.) This recycling will not affect the performance of the pollution control devices. There is a potential for PM generation at the plant any time FRI handles raw materials. At each material transfer point in the plant, a baghouse will control PM emissions. The plant will have twenty of these baghouses. They effectively limit the concentration of dust in the air stream. In addition to the grain loading limitation for the baghouses and the mass emission rates for the ESPs, the Department has set opacity limitations for these devices. Opacity is the visual density of PM. FRI will install a CEM for opacity on the ESPs for the kiln system and the clinker cooler. Baghouses and ESPs are commonly used in the cement industry nationally and internationally. The performance of the plant's baghouses and ESPs will be subject to empirical testing to ensure compliance with PM/PM10 emission limits before the Department issues FRI an operating permit. Baghouses and ESPs provide an equivalent degree of PM emission control in cement kilns and clinker coolers. FRI stipulates that the permit should contain a condition requiring the applicant to submit the manufacturer's performance guarantee to the Department prior to the commencement of construction of the plant. FUGITIVE EMISSIONS Unconfined PM emissions (fugitive emissions) are particles that are not collected and discharged through a stack or vent. Fugitive emissions may result from the storage and handling of coal ash. They may also be caused by mining activities and vehicles traveling on paved and unpaved roads. The Department establishes opacity limits on fugitive emissions because there is no way to establish a mass emission rate. FRI has provided reasonable assurances that the plant will meet the opacity limits for fugitive emissions by ensuring an adequate moisture content in all materials received at the plant such as coal ash. The utility supplying the coal will add approximately eight to ten percent moisture to the coal ash prior to delivery at the plant. At that level of moisture, the coal ash will generate virtually no fugitive emissions when FRI personal moves it with a front-end loader or any other mechanical device. FRI will place water lines, hoses and sprinklers near all storage stock piles. The plant operators will be trained in basic environmental compliance. They will perform visual inspections of materials before handling them. If an inspection reveals a lack of excess surface moisture, the plant operators will wet the material with the sprinklers. To eliminate unconfined particulate matter emissions from the material handling activities, FRI agrees to store all material under cover and on compacted clay or concrete. FRI will pave the plant area to limit the generation of fugitive emissions from trucking and equipment traffic. FRI will maintain and operate a sweeper truck at the plant to limit dust buildup on paved surfaces. FRI will not emit any fugitive emissions at the tire feeder mechanism because the kiln, precalciner and preheater are all under a negative pressure. The method of feeding tires through a double air lock system will also prevent fugitive emissions. FRI has agreed to special permit conditions requiring it to "immediately collect" any spilled CKD to prevent fugitive emissions. FRI also has agreed that the Department may incorporate into the permit a specific condition relative to a fugitive emission protocol. MERCURY Mercury is a metal that naturally occurs in the earth's crust. The plant's feed materials and fuels contain mercury. The temperatures in the kiln system cause the mercury in the feed material and fuels to become a part of the gas stream. As mercury in a gaseous state passes through the preheater, some of it will condense and solidify onto particulate matter. Additional mercury will condense as the gas stream approaches the electrostatic precipitator which will have operating temperatures between 220 and 350 degrees Fahrenheit. At this point, virtually all of the mercury will have condensed onto solid particles. The raw mill will collect some of the solid particles containing mercury. The ESP will also collect the particles and return them to the cement kiln process. Some of the mercury will leave the plant in the finished cement product. The plant will exhaust only a small fraction of the particles containing mercury with the stack gas. The record contains evidence of a mass balance calculation for mercury emissions of 180 pounds per year. This calculation was based on a worst-case scenario and assumed that all the mercury entering the plant would be released into the atmosphere. The Significant Emission Rate for mercury that would require a PSD/BACT review is 200 pounds per year. There are no demonstrated mercury controls or add-on controls for limiting mercury emissions in cement plants. Nevertheless, FRI has provided reasonable assurances that the plant's mercury emissions will be below the 200 pounds per year threshold. Evidence to the contrary is unpersuasive. FRI is willing to accept a permit condition limiting the total input of mercury to below 200 pounds. FRI will demonstrate compliance with this condition through monthly sampling and analysis of the raw mill feed, coal and tires. BERYLLIUM The combustion of coal in the kiln and calciner burner and the combustion of number two fuel oil in the raw mill auxiliary air heater will generate small quantities of beryllium as particulate emissions. The ESP on the kiln will control these emissions. The proposed emission rate for beryllium is .0006 tons per year. The PSD Significant Emission Rate for beryllium is .0004 tons per year. The Department will determine the final emission limit for beryllium after receiving the results of future stack tests. MODELING FRI performed air quality modeling to estimate the ambient air concentrations of emissions from the proposed facility based on many factors and highly-developed technology. FRI used three air quality models: (a) the Industrial Source Complex (ISC) model; (b) the SCREEN model; and (c) the long- range transport model (MESOOPUFF). The modeling included maximum emission rates (or worst case scenarios) for all expected pollutants. The modeling was very conservative because it incorporated FRI's initially proposed emission rates which were higher than the emission rates ultimately proposed in the draft permit. All predicted air toxic impacts, although not regulated, were below the Department's draft ambient reference concentrations. AMBIENT AIR QUALITY STANDARDS (PRIMARY AND SECONDARY) Primary air quality standards are limits on the concentration of materials in the ambient air to protect human health. Secondary air quality standards are limits on the concentration of materials in the ambient air necessary to protect public welfare, including, plants, animal life, visibility and the enjoyment of property. FRI provided reasonable assurance through air quality modeling that FRI would meet primary and secondary ambient air quality standards. IMPACT ON CLASS I AREAS/PSD INCREMENTS Class I air quality areas are areas with a pristine environment. The two closest Class I areas to the proposed plant are the Okefenokee Swamp and the Chassahowitzka National Wilderness area. Class II air quality areas are any areas of the state that have not been designated Class I areas. They include all areas around the proposed facility. Class I and II PSD increments are the incremental increases in air pollutants allowed in Class I and II areas respectively. FRI's air quality modeling provides reasonable assurance that the plant will not adversely impact Class I areas or exceed the Class I and II PSD increments. Additionally, the plant will not cause any visibility-related impacts in the Class I areas. COMPLETENESS OF APPLICATION The application contains complete information for each item on Form No. 62-210.900(1), Florida Administrative Code. It identified the applicant, the facility location, and the proposed activity. The application described each emission unit and the pollution control methods. FRI enclosed the appropriate application fee. It was sealed by a Florida Professional Engineer. In addition to the completed application form, FRI submitted a report with added detail in support of the application. This report described the applicant and the facility location. It included: a project description; a review of applicable rules; a BACT proposal; an air quality review; a description of stack height design; and, a statement of environmental impacts. FRI submitted documentation to support the report including emission calculations, detailed process diagrams, equipment lists, area map, site map, plot plan, plot plan with emission points, process flow diagram, and a description of the relationship of CO and NOx emissions. FRI submitted additional information in response to the Department's requests. The application as submitted into evidence and explicated during the hearing is substantially complete. CONSTRUCTION SCHEDULE FRI's application provides a start date, January 1, 1996, and completion date, December of 1997. The estimated time for the construction of the facility is two years. FRI submitted a detailed construction schedule into evidence. However, it will not be the schedule that FRI ultimately follows. FRI will furnish the Department with a final construction schedule after FRI selects the contractor. The construction schedule will not affect the two-year construction schedule. MALFUNCTIONS Petitioner failed to present any credible evidence that the malfunction provisions of the proposed permit were inadequate to ensure that FRI would not exceed the emission limits in the draft permit or interim determination. The presence of tires in the kiln at the time of a malfunction will not affect emissions because the tires will completely burn in five to six seconds. During the combustion process, any metal in the tires will completely disintegrate. Furthermore, there is no persuasive evidence that "Puff's Disease" is present at cement kilns where tires are continuously fed into the kiln system. Variability in stack gas flow causes Puff's Disease when an emission unit does not operate in a uniform steady state. ODORS The permit prohibits any objectionable odors from the proposed facility. There was no persuasive evidence that the plant will emit objectionable odors. DIOXIN FORMATION There is no persuasive evidence that the permit fails to adequately address the potential for dioxin formation. There is a potential for dioxin formation in ESPs with inlet gas temperatures from 450 degrees Fahrenheit to 750 degrees Fahrenheit. Dioxin will not form at the plant because the inlet gas temperatures of the ESP will range between 230 and 430 degrees Fahrenheit. If the temperature of gas in the plant's ESP ever rises above 450 degrees Fahrenheit, it will not remain at that temperature long enough to form dioxins. Particulate matter containing carbon contributes to dioxin formation. The particulate matter at the proposed plant will contain small amounts of organic carbon. The potential for dioxin formation on this basis is little or none. The Department has not adopted any standards or rules regulating dioxin formation or emission in cement plants. MANUFACTURER'S GUARANTEE The record does not contain a manufacturer's guarantee relative to the emission rate of any pollutant for any of the plant's equipment. Polysius Corporation, designed the facility. It will make whatever design modifications are necessary, if any, for FRI to comply with permit conditions before the Department issues an operational permit. As an additional permit condition, FRI shall provide the Department with the final designs and the manufacturer's guarantee for the ESPs before construction begins. FRI has never owned or operated a cement plant. However, FRI's project manager has forty years of experience in the cement industry, including experience working as Chief Executive Officer and President of Polysius Corporation. OTHER FLORIDA FACILITIES Florida Crushed Stone (FCS) operates a cement plant located in Brooksville, Florida. Polysius Corporation designed the FCS plant which was built in the 1980's. There are similarities between the FCS plant and the proposed plant. The FCS plant has a clinker production rate of approximately 75 tons per hour. The proposed facility has a clinker production rate of approximately 95 tons per hour. The physical size of the FCS kiln is approximately the same size as the proposed kiln. Like the proposed plant, the FCS plant uses a dry process to make cement. The FCS kiln recycles almost all of its CKD. There are also some differences between FCS and the proposed plant. FCS has a preheater but not a precalciner. It uses a baghouse instead of an ESP to control kiln emissions. The proposed plant and the FCS plant use different raw feed materials. The FCS plant is unique in that it has a coal-fired power plant built next to it. The power plant and the cement plant exhaust their stack gases through a common baghouse. FCS's heated clinker cooler gas is used in part as combustion air for the power plant. The power plant's exhaust gas is used for drying the raw materials fed to the cement plant. FCS's plant has a SO2 emission limit of 50 pounds per hour. It's NOx BACT limitation is about 4.8 pounds per ton of clinker. The coal feed rate at FCS's plant is about 10 tons per hour. Up to 15 percent of its BTU value can be from tires. This amounts to 123 tires an hour, or about a third of the BTU value specified in the proposed permit. Florida Mining and Material (FMM) also operates a plant in Brooksville, Florida. Polysius Corporation designed the FMM plant over twenty years ago. The FMM plant has two kilns with a clinker production capacity of about 75 to 80 tons per hour for each kiln. The FMM kilns are dry process. They both have preheaters but no precalciners. The FMM kilns are approximately the same physical size as the proposed kiln. Both FMM kilns have a single firing point. They recycle 99.9 percent of their CKD. Separate baghouses control emissions from the FMM kilns. There are differences in the raw feed materials used at the FMM kilns and the proposed plant. Rinker Corporation (RC) operates a cement plant in Dade County, Florida. It was built sometime in the early 1970's. The RC plant has two kilns which are about 400 feet long and use a wet process to make cement. The designer of the RC plant is unknown. Each of the RC kilns produce about 35 to 40 tons of clinker per hour. Neither of them has a preheater or a precalciner. Both of them control PM with ESPs. They do not recycle 100 percent CKD. The RC plant is not similar to the proposed plant. However, the FCS plant and the FMM plant are sufficiently similar to the proposed plant to provide an expert witness with a basis for comparing their processes, operations, and potential emissions. The differences in the raw materials used by these plants and the differences in design characteristics between these plants and the proposed plant are within an expected range of other cement plants. The basic chemistry involved in making cement at FCS, FMM and the proposed plant is the same. Test results from FCS and FMM can be normalized for making comparisons with the proposed plant.
Recommendation Based on the Findings of Fact and Conclusions of Law set forth above, it is recommended that Respondent Department of Environmental Protection issue a Final Order granting permit number AC01-267311/PSD-FL-228 as proposed in the Department's Intent to Issue dated September 29, 1995, as modified by the Interim Determination of November 17, 1995, and with the additional conditions detailed in this Recommended Order. DONE and ENTERED this 23rd day of July, 1996, in Tallahassee, Leon County, Florida. SUZANNE F. HOOD, Hearing Officer Division of Administrative Hearings The DeSoto Building 1230 Apalachee Parkway Tallahassee, Florida 32399-1550 (904) 488-9675 SUNCOM 278-9675 Filed with the Clerk of the Division of Administrative Hearings this 23rd day of July, 1996. APPENDIX CASE NO. 95-5531 The following constitutes the undersigned's rulings on each of the parties' proposed findings of fact. Petitioner's Proposed Findings of Fact. Accepted. See Conclusions of Law. First sentence accepted in FOF 104. Reject balance of paragraph as contrary to more persuasive evidence. 3-16. Accept as subordinate to FOF 1-116. Relevant only as background information to summarize the agency's review process. 17. Accept in part, reject in part. See FOF 19, 22-72, 79- 86. No credible evidence that proposed plant will emit lead or mercury in excess of PSD Significant Emission Rates. 18-19. Accept as subordinate to FOF 10, 103-104. Accept as restated in FOF 105-116. Accepted. The record contains preliminary designs showing engineering features and specifications. The record, considered in its entirety, is sufficient to determine that FRI has met its burden of providing reasonable assurances. There is no mechanism for disposal of CKD because FRI will recycle 100 percent of the CKD. Accepted as restated in FOF 96-97. FRI will have to provide a more detailed construction schedule when the Department issues the construction permit. 23-24. Accepted. FRI will select the contractor and vendors after receiving the construction permit. 25. Accepted. See FOF 22-23, 35-36, 44, 70. CEMs do not control emissions but they assist the plant operator in making necessary adjustments to achieve certain emission rates. 26-33. Accepted as subordinate to FOF 105-116. 34-35. Reject. The record contains sufficient information about emissions from other Florida cement plants for an expert like Dr. Koogler to draw comparisons with the emissions from the FRI plant. Accept that emission data may need to be "normalized" when comparing the pollutants of one plant to another to allow for differences in raw feed material and fuels. Reject second sentence as not supported by the record. Dr. Koogler made all of his comparisons of the Florida cement plants after considering the technical differences between the plants. In some instances Dr. Koogler analyzed the technical differences in the physical design of the plants to explain the differences in emission rates. Accept all but the last sentence. AP-42 contains emission factors for all types of cement plants including the type at issue here. Accept only as to information under consideration early in the permit review process and before the formal hearing. Accept as if incorporated in 105-116. 40-50. Accept in part and reject in part. See FOF 57-72. 51-59. Accept in part and reject in part. See FOF 39-52. 60-78. Accept in part and reject in part. See FOF 22-38, 53-56. 79-87. Accept in part and reject in part. See FOF 1-116. Using tires as fuel is discussed through out the Recommended Order. The description in the record of the tire feeder mechanism is sufficient to determine that it will meet all applicable standards. 88. Reject. See FOF 87-92. 89-93. Accept in part and reject in part. See FOF 79-84. Respondent Department's Proposed Findings of Fact. 1-2. Accept in FOF 1-21. 3. Accept in FOF 22. 4-6. Accept in FOF 23-31. 7-11. Accept in FOF 39-52. 12. Accept in FOF 57-72. 13. Accept in FOF 53-56. 14. Accept in FOF 17-72. 15. Accept in FOF 93-95. 16-26. Accept in FOF 32-38. 27-31. Accept in FOF 39-52. 32-45. Accept in FOF 57-72. 46. Accept in FOF 53-56. 47. Accept in FOF 79-84. 48. Accept in FOF 73-78. 49-51. Accept in FOF 9 and 77. 52-53. Accept in FOF 96-97. 54-59. Accept in FOF 105-116. Accept in 87-92. Accept in FOF 103-104. Respondent FRI's Proposed Findings of Fact. 1. Accepted. 2-12. Accept in or as subordinate to FOF 1-16. 13. Accept in FOF 49, 78, and 84. 14-15. Accept in or as subordinate to FOF 17-21. 16-18. Accept in or as subordinate to 39-52. 19. Accept in or as subordinate to FOF 22. 20-22. Accept in or as subordinate to FOF 23-31. 23. Accept in or as subordinate to FOF 53-56. 24. Accept in or as subordinate to FOF 57-72. 25. Accept in or as subordinate to FOF 79-84. 26-29. Accept in or as subordinate to FOF 87-92. 30-37. Accept in or as subordinate to FOF 32-38. 38-42. Accept in or as subordinate to FOF 53-56. 43-71. Accept in or as subordinate to FOF 57-78. 72-77. Accept in or as subordinate to FOF 79-83. 78-88. Accept in or as subordinate to FOF 39-52. Accept in FOF 96-97. Accept in FOF 98. 91-93. Accept in or as subordinate to FOF 87-92, and 99-104. COPIES FURNISHED: Priscilla N. Harris, Esquire Stewart Harris, Esquire Post Office Box 702 Green Cove Springs, Florida 32040 Segundo J. Fernandez, Esquire Timothy P. Atkinson, Esquire Oertel, Hoffman, Fernandez et al. 2800 Blair Stone Road Tallahassee, Florida 32399-2400 Jefferson M. Braswell, Esquire W. Douglas Beason, Esquire Department of Environmental Protection 2600 Blair Stone Road Tallahassee, Florida 32399-2400 Virginia B. Wetherell, Secretary Department of Environmental Protection Douglas Building 3900 Commonwealth Boulevard Tallahassee, Florida 32399-3000 Kenneth Plante, Esquire Department of Enviromental Protection 3900 Commonwealth Boulevard Tallahassee, Florida 32399-3000
Findings Of Fact The Sound Transportation Planning Coalition, Inc., and The Florida Lung Association have standing to bring this action. This action is brought pursuant to Section 120.56, Florida Statutes, and challenges the validity of the repeal of Rule 17-2.04(8), Florida Administrative Code. On or about July 8, 1977, the Department of Environmental Regulation published a notice of rule making for adoption of proposed amendments to Rule 17-2.04(8), Florida Administrative Code, in the Florida Administrative Weekly. This Publication included notice of a hearing to be held by the Environmental Regulation Commission for the consideration of the adoption of proposed amendments to the subject rule. At least thirty (30) days notice prior to the foregoing hearing by the Environmental Regulation Commission was also given in newspapers of general circulation around the state. For the purposes of this proceeding the parties have stipulated that the Department of Environmental Regulation complied with the provisions of Section 120.54(1), Florida Statutes, regarding notice of hearing on the proposed rule which was an amendment to an existing rule. The Environmental Regulation Commission took action on August 11, 1977, with regard to the matters pertinent to this Proceeding and no notice other than that referred to above in paragraph 3 pertinent to the action taken by the Environmental Regulation Commission was given by the Department of Environmental Regulation. The rule making action proposed by the Department of Environmental Regulation was the amendment of Rule 17-2.04(8), Florida Administrative Code, which amendment, according to the Department's notice, was designed to make the indirect source permit system workable and yet maintain ambient air quality standards for carbon monoxide. The amendment was expected to reduce the number of permit reviews required and to limit the evaluation for each indirect source to one pollutant, carbon monoxide. The action taken by the Environmental Regulation Commission on behalf of the Department of Environmental Regulation was the complete repeal of Rule 17-2.04(8), Florida Administrative Code. After having considered the proposed amendments to the subject rule it was apparently the decision of the Environmental Regulation Commission that the better action would be the complete repeal of the rule and that is the action they took. The Department of Environmental Regulation prepared an Economic Impact Statement directed to the impact of the proposed amendments to the subject rule. The parties have stipulated that for the purpose of this proceeding only, the Department of Environmental Regulation complied with the provisions of Section 120.54(2)(a), Florida Statutes, with regard to the proposed amendments to the subject rule and the said Economic Impact Statement would have been satisfactory for the adoption of the proposed amendments had they been adopted. No Economic Impact Statement directed to the repeal of the subject rule was prepared. No individual in the Department of Environmental Regulation was instructed to prepare an Economic Impact Statement for the repeal of Rule 17- 2.04(8), Florida Administrative Code. The Department at no time prior to the hearing held by the Environmental Regulation Commission on the proposed amendments to the subject rule, gave specific notice to any individuals that it intended to repeal Rule 17-2.04(8), Florida Administrative Code.
