NSPS for Dc Boilers Burning Residual Oil

Size: px

Start display at page:

Download "NSPS for Dc Boilers Burning Residual Oil"

Cornelia Richards
5 years ago
Views:

1 Minnesota Pollution Control Agency AQ Doc. # 8.07 February 1998 Facts about NSPS for Dc Boilers Burning Residual Oil In an effort to regulate new sources of air pollution and ensure that those sources pollute less than older sources, the U.S. Environmental Protection Agency (EPA) has put forth the New Source Performance Standards (NSPS), affecting a variety of new or modified equipment and facilities. In part, the performance standards place limits on emissions and require performance testing, recordkeeping, reporting, and monitoring. This fact sheet examines the performance standards affecting certain boilers that burn residual oil alone or as a backup to natural gas. These standards are found in NSPS subpart Dc, Standards of Performance for Small Industrial-Commercial-Institutional Steam Generating Units (Dc boilers), Code of Federal Regulations (CFR), Title 40, Part 60, Sections 60.40c to 60.48c. If you burn a different type of fuel than residual oil, the information in this fact sheet does not apply to you. The MPCA does have copies of fact sheets available for owners/operators of Dc boilers which burn either distillate oil or natural gas. You can get a copy of either of these fact sheets by contacting the Document Coordinator at the number listed at the end of this fact sheet. What are the Dc boiler standards? The subpart Dc standards of performance are a set of requirements governing the Attached to this fact sheet is a completed, generic Form CD-01. If you are a permit applicant and you have a Dc boiler that burns residual oil, you may use this attached generic CD-01 form to complete your permit application. Since the attached CD-01 form represents a generic facility, you may need to modify it to represent your actual facility. combustion of various fuels and the monitoring of emissions from small boilers. Do the Dc boiler standards apply to me? Standards in subpart Dc apply to steam generating units for which construction, modification, or reconstruction was started after June 9, 1989, and that have a maximum design heat input capacity between 10 million Btu/hr and 100 million Btu/hr. The subpart Dc performance standard applies to units that combust any of several fuel types, including coal, oil, natural gas, and wood. How does subpart Dc define residual oil and natural gas? Subpart Dc defines residual oil as crude oil and fuel oil that is not distillate oil. Natural gas is defined as (1) a naturally occurring mixture of hydrocarbon and non-hydrocarbon gases found in geologic formations beneath the earth s surface, of which the principal constituent is methane, or (2) liquefied Minnesota Pollution Control Agency, 520 Lafayette Rd. N., St. Paul, MN (651) , toll-free , TDD/TTY (651) Upon request, this material can be made available in alternative formats.

2 petroleum (LP) gas, as defined in ASTM D What is required of facilities that have Dc boilers that burn residual oil alone or with natural gas? A facility combusting residual oil alone or with natural gas must follow the standards, compliance and performance test methods, and reporting requirements of subpart Dc. Since there are no established limits for natural gas in subpart Dc, the standards for units that combust oil are all that apply. What pollutant standards are contained in subpart Dc? There are two pollutant standards for sulfur dioxide (SO 2 ) compliance. You must comply with one of the following standards: an emission limit of 0.5 pounds of SO 2 per million Btu heat input, or a fuel oil sulfur limit of 0.5 percent sulfur by weight. NOTE: If residual oil is used, the emission limit of 0.5 pounds of SO 2 per million Btu heat input is usually the applicable standard, since residual oil generally has a higher sulfur content than 0.5 percent. How do I demonstrate compliance with the emission limit? The standard specified that you must use a continuous emission monitoring system (CEMS) to determine your 30-day SO 2 emission rate. The CEMS must be certified by the MPCA. Am I subject to any opacity standards? A standard for opacity applies only to Dc boilers with heat input capacities between 30 and 100 million Btu/hour. The opacity standard states that a boiler may not discharge gases with more than 20 percent opacity, except for one 6-minute period per hour of not more than 27 percent opacity. Do I have to conduct any testing on my boiler? Every Dc boiler with a heat capacity of 30 million Btu/hour or greater must be tested for SO 2 and opacity limit compliance. EPA Reference Method 9 must be used when conducting any compliance tests regarding opacity and Method 19 must be used for SO 2 testing. Do I have to monitor the opacity of my Dc boiler? If you have a Dc boiler with heat input capacity of 30 million Btu/hour or greater, you must install, certify, operate, and maintain a continuous opacity monitoring system (COMS) on that boiler. What are the recordkeeping and reporting requirements for facilities with Dc boilers? The owner or operator of the facility must keep records and submit written notification of the following, as applicable, to the MPCA: A. Date of boiler construction or reconstruction, and anticipated and actual startup dates (within the timeframe specified in subpart A of the NSPS). These notification must include the following three elements: The design heat-input capacity of the boiler and identification of the fuels to be combusted in the boiler; Doc. # 8.07, Page 2

3 the annual capacity at which you anticipate operating the boiler based on all fuels fired and based on each individual fuel fired; and if an emerging technology will be used for controlling SO 2 emissions. B. Any performance test data from any performance tests, within 45 days following the completion of the test. C. Facilities with boilers subject to the opacity or SO 2 limits listed above must submit quarterly excess-emissions reports, postmarked by the 30th day following the end of the reporting period. A quarterly report must contain the following information: 1) Calendar dates covered in the reporting period; 2) Each 30-day average SO 2 emission rate (ng/j or lb/million Btu), or 30-day average sulfur content (weight percent), calculated during the reporting period, ending with the last 30-day period in the quarter; reasons for any noncompliance with the emission standards; and a description of any corrective actions taken; 3) Each 30-day average percent of potential SO 2 emission rate calculated during the reporting period, ending with the last 30-day period in the quarter; reasons for any noncompliance with the emission standards; and a description of any corrective actions taken; 4) Identification of any operating days for which SO 2 data have not been obtained by an approved method for at least 75 percent of the operating hours; justification for not obtaining sufficient data; and a description of any corrective action taken; 5) Identification of any times when emissions data have been excluded from the calculation of average emission rates; justification for excluding data; and a description of corrective actions taken if data have been excluded for periods other than those during which residual oil was not combusted in the boiler; 6) Identification of whether averages have been obtained based on CEMS rather than manual sampling methods. If a CEMS is used, submit the following: Identification of any times when the pollutant concentration exceeded the full span of the CEMS. Description of any modifications to the CEMS that could affect the ability of the CEMS to comply with Performance Specifications. Results of quarterly accuracy assessments as required under Appendix F, Procedure 1. 7) The owner or operator of each facility with a Dc boiler must record and maintain records of the amounts of each fuel combusted during each day. All of the above submittals should be sent to the Compliance Determination Unit at the address listed at the end of this fact sheet. Is there anything else I should know about the NSPS regulations? Yes. If you are subject to Subpart Dc, or any other subpart of the NSPS, you are automatically subject to the NSPS General Provisions. The General Provisions describe the performance testing, recordkeeping, reporting, and monitoring provisions that apply to every NSPS affected source. The NSPS General Provisions are found in Subpart A of 40 CFR 60. The MPCA has a fact sheet on the NSPS General Provisions. If you would like a copy of the fact sheet, contact the Air Quality Document Coordinator at the number listed at the end of this fact sheet. Doc. # 8.07, Page 3

4 Although I am subject to the Dc standards, am I still eligible for a Registration Permit? Any facility with a boiler that combusts residual oil and which is subject to Subpart Dc must have an air emissions permit. Being subject to Subpart Dc does not mean you can t get a registration permit. There are two registration permit options that may work. If the sum of the Potential to Emit (PTE) of all emission units at your facility is below the levels for pollutants shown in the following table, you may qualify for an Option A Registration Permit: Pollutant Tons Per Year (TPY) PM 100 SO 2 50 VOC 100 a single HAP 10 Combined HAPs 25 PM NO X 100 CO 100 Lead 0.5 If the PTE for any one pollutant from all emission units at your facility is above the levels shown in the table above, you may still be eligible for an Option D Registration Permit if the total actual emissions for the previous 12 months from all emission units is below the thresholds listed in the following table: Pollutant TPY PM 50 SO 2 50 VOC 50 a single HAP 5 Combined HAPs 12.5 PM 10 (attainment area) 50 PM 10 (nonattainment area) 25 NO X 50 CO 50 Lead 0.5 Who can I call if I have questions? For more information, contact the following: Permit Technical Advisor: (651) (800) Document Coordinator: (651) TTY: (651) (800) MPCA Mailing Address: 520 Lafayette Road North St. Paul, MN GENERIC CD-01 FORM FOR SUBPART Dc BOILERS THAT COMBUST RESIDUAL OIL The attached sample CD-01 form has been developed to assist permit applicants who are subject to Subpart Dc. This form lists the requirements of subpart Dc as required in the CD-01 form. You should review subpart Dc and the requirements listed in this form to determine which requirements apply to your boiler. After you have made your determination, you should transfer the appropriate requirements from this form to your facility-specific CD-01 application form. Since this form is generic, it may contain requirements that do not apply to your specific boiler. Please note that the information listed in italics is to help you determine whether a limit applies to your boiler. The italics information should not be transferred to your CD-01 form. Doc. # 8.07, Page 4

5 ) 5b) 5c) ion Requirement Requirement Permittee has the option of complying with an SO 2 emission limit or a limit on the sulfur content of the fuel oil. Sulfur Dioxide: Less than or equal to 0.5 lb/million Btu heat input OR Sulfur Content of Fuel: Less than or equal to 0.5 percent by weight For boilers with heat input capacities between 30 and 100 million Btu/hr: Opacity: Less than or equal to 20 percent opacity using 6 minute average, except for one 6 minute period per hour of not more than 27 percent opacity, using Method 9 Type and (d) If the SO 2 emission limit is used: Performance Test: Conducted over 30 consecutive operating days beginning within 30 days after achieving the maximum production rate but not later than 180 days after initial startup. Use continuous emission monitoring system (CEMS) and Method 19 to determine the hourly SO 2 emission rate and the 30 day average SO 2 emission rate. Or, if a fuel oil sulfur limit is used and the boiler heat input capacity is greater than 30 million Btu/hr: Performance Test: Sample and analyze the oil in the initial tank of oil to be fired and in each new shipment of oil. to measure the sulfur content. Or, if a fuel oil sulfur limit is used and the boiler heat input capacity is 10 to 30 million Btu/hr: Performance Test: Obtain fuel supplier certifications for each shipment of oil, showing the sulfur content of the fuel burned. If Opacity limit applies: Performance Test: Due 180 days after initial startup or within 60 days of achieving maximum production capacity, to measure opacity If the SO 2 emission limit is used: SO 2 Monitoring: SO 2 emission limit is based on the average SO 2 emission rate for 30 consecutive boiler operating days. A separate performance test is completed at the end of each operating day, and a new 30-day average SO 2 emission rate is calculated. If the SO 2 emission limit is used: SO 2 monitoring: use continuous emission monitoring system (CEMS) and Method 19 to determine the hourly SO 2 emission rate and the 30-day average SO 2 emission rate.

6 inn. R , subp. Performance Test Notification (written): due 30 days before each performance test. Notification of the Date Construction Began: Due 30 days after start of construction Notification of the Anticipated Date of Initial Startup: Due 60 days prior to anticipated date of initial startup Notification of the Actual Date of Initial Startup: Due 15 days after initial startup (Note to Permittee: these three notifications are to include the design heat input capacity of the affected unit and identification of fuels to be combusted) 2 Performance Test Plan: due 30 days before Performance Test 4 Performance Test Pre-meeting: Due 30 days before Performance Test Minn. R , Performance Test Report: Due 45 days after Performance Test 2 Performance Test Report - Microfiche copy: Due 105 days after Performance Test 1 Testing Frequency Plan: due 20 days after Performance Test. The plan shall specify a testing frequency using the test data based on MPCA guidance. Future performance tests based on year (12 month), 36 month, and 60 month intervals, or as applicable, shall be required on written approval of MPCA Record the amount of each fuel combusted each day. ontaining at least 20 percent fibers from paper recycled from consumers.

AIR EMISSION PERMIT NO IS ISSUED TO. Order of St. Benedict/St. John's Abbey

AIR EMISSION PERMIT NO IS ISSUED TO. Order of St. Benedict/St. John's Abbey AIR EMISSION PERMIT NO. 14500008-002 IS ISSUED TO Order of St. Benedict/St. John's Abbey Order of St. Benedict/St. John's Abbey Power Plant Collegeville, Stearns County, MN 56321 The emission units, control