Title 40—Protection of Environment--Volume 1
PART 52—APPROVAL AND PROMULGATION OF IMPLEMENTATION PLANS
§ 52.1322   Original Identification of Plan Section.
(a) This section identifies the original “Air Implementation Plan for the State of Missouri” and all revisions submitted by Missouri that were Federally approved prior to July 1, 1999.
(b) The plans were officially submitted on January 24, 1972.
(c) The plan revisions listed below were submitted on the dates specified.
(1) Budget and manpower projections were submitted by the State Air Conservation Commission (ACC) on February 28, 1972. (Non-regulatory)
(2) A memorandum from the State Air Conservation Commission concerning the effects of adopting Appendix B to NO 2 emissions in the St. Louis area was submitted on March 27, 1972. (Non-regulatory)
(3) The determination of the CO air quality data base on the St. Louis area was submitted on May 2, 1972, by the Air Conservation Commission. (Non- regulatory)
(4) The emergency episode operations/communications manual for the Kansas City area was submitted on May 11, 1972, by the State Air Conservation Commission. (Non-regulatory)
(5) Amendments to the Air Conservation Law, Chapter 203, and plans for air monitoring for outstate Missouri were submitted July 12, 1972, by the Air Conservation Commission.
(6) The following amendments to the St. Louis and Kansas City outstate plans were submitted August 8, 1972, by the State ACC: Air Conservation Law, Chapter 203; Kansas City Ordinance, Chapter 18; Regulations XVIII, XX, XXVI (St. Louis); Regulations X, XII, XVII (Kansas City) and Regulations S-11, S-X111 and S-X11 (outstate).
(7) Letters discussing transportation control strategy for Kansas City Interstate AQCR submitted by the State ACC on May 11 and 21, 1973. (Non-regulatory)
(8) Alert plan for St. Louis County and outstate Missouri was submitted on May 24, 1973, by the ACC. (Regulatory)
(9) Copy of the State's analysis of ambient air quality in the Missouri portion of the Metropolitan Kansas City Interstate Air Quality Control Region and recommendation that the area not be designated as an Air Quality Maintenance Area submitted by the Missouri Air Conservation Commission on April 11, 1974. (Non-regulatory)
(10) Copy of the State's analysis of the Missouri portion of the Metropolitan St. Louis Interstate Standard Metropolitan Statistical Area (SMSA), the Columbia SMSA and the Springfield SMSA and recommendations for the designation of Air Quality Maintenance Areas submitted by the Missouri Air Conservation Commission on May 6, 1974. (Non-regulatory)
(11) Compliance Schedules were submitted by the Missouri Air Conservation Commission on June 3 and October 1, 1976.
(12) Compliance Schedules were submitted by the Missouri Air Conservation Commission on November 23, 1976.
(13) On August 28, 1978, the following revisions were submitted by the Missouri Department of Natural Resources:
(i) The recodification of Missouri regulations of July 1, 1976, now contained in Title 10, Division 10 of the Code of State Regulations.
(ii) Title 10, Division 10, Chapter 6 of the Code of State Regulations which contains air quality standards, definitions, and reference methods.
(iii) Missouri Rule 10 CSR 10-2.200; Rule 10 CSR 10-3.150; and Rule 10 CSR 10-4.190 pertaining to control of SO 2 from indirect heating sources.
(iv) Missouri Rule 10 CSR 10-2.030; Rule 10 CSR 10-3.050; Rule 10 CSR 10-4.030; and 10 CSR 10-5.050 exempting certain process sources from the process weight regulations for particulate matter.
(v) Missouri Rule 10 CSR 10-2.190; Rule 10 CSR 10-3.140; Rule 10 CSR 10-4.180; and Rule 10 CSR 10-5.280 which contain the “Standards of Performance for New Stationary Sources,” found at 40 CFR part 60 as in effect on January 18, 1975.
(vi) Missouri Rule 10 CSR 10-2.060; Rule 10 CSR 10-3.080; Rule 10 CSR 10-4.060; and Rule 10 CSR 10-5.090 which require continuous opacity monitors for certain sources.
(vii) Missouri Rule 10 CSR 10-5.140 for determining settlable acid and alkaline mists is rescinded.
(viii) The EPA is taking no action on Rule 10 CSR 10-5.100; 10 CSR 10-2.050, and 10 CSR 10-3.070 which limit fugitive particulate emissions from the handling, transporting and storage of materials in the State of Missouri.
(14) On March 12, 1979, the Missouri Department of Natural Resources submitted Rule 10 CSR 10-3.100 and Rule 10 CSR 10-5.150 establishing revised SO 2 emission limits for primary lead smelters.
(15) On March 1, 1979, the Missouri Department of Natural Resources submitted a revision of regulation 10 CSR 10-5.110 revising the allowable emission rates of sulfur dioxide from Union Electric's Sioux and Labadie power plants.
(16) On July 2, 1979, the State of Missouri submitted a plan to attain the National Ambient Air Quality Standards for the Kansas City and St. Louis areas of the state designated nonattainment under section 107 of the Clean Air Act, as amended in 1977. Included in the plan are the following approved regulations as amended, in part, in subsequent submittals:
(i) Rule 10 CSR 10-2.210 and 10 CSR 10-5.300 Control of Emissions from Solvent Metal Cleaning are approved as RACT;
(ii) Rule 10 CSR 10-2.220 and 10 CSR 10-5.310 Liquified Cutback Asphalt Paving Restriated are approved as RACT;
(iii) Rule 10 CSR 10-5.220 Control of Petroleum Liquid Storage, Loading and Transfer (St. Louis) is approved as RACT.
(iv) Rule 10 CSR 10-2.260 Control of Petroleum Liquid Storage, Loading and Transfer (Kansas City) is approved as RACT;
(v) Rule 10 CSR 10-5.030 Maximum Allowable Emission of Particulate Matter from Fuel Burning Equipment Used for Indirect Heating is approved as RACT;
(vi) Rule 10 CSR 10-5.090 Restriction of Emission of Visible Air Contaminants is approved as RACT;
(vii) Rule 10 CSR 10-5.290 More Restrictive Emission Limitations for Sulfur Dioxide and Particulate Matter in South St. Louis is approved as RACT;
(viii) Rule 10 CSR 10-2.040 Maximum Allowable Emission of Particulate Matter from Fuel Burning Equipment Used for Indirect Heating is approved as RACT;
(ix) Rule 10 CSR 10-2.240 Restriction of Emissions of Volatile Organic Compounds from Petroleum Refinery Sources is approved as RACT;
(x) Rule 10 CSR 10-2.250 Control of Volatile Leaks from Petroleum Refinery Equipment is approved as RACT; and
(xi) Rule 10 CSR 10-2.230 and 10 CSR 10-5.330 Control of Emissions from Industrial Surface Coating Operations is approved as RACT.
(17) On July 2, 1979, the Missouri Department of Natural Resources submitted variances (compliance schedules) for Union Electric Company's Labadie power plant, River Cement Company, and Monsanto Company's Queeny plant. The compliance schedules require these sources to comply with revised Rule 10 CSR 10-5.090. In addition, the Labadie power plant is required to come into compliance with Rule 10 CSR 10-5.030.
(18) On April 7, 1980 the State of Missouri submitted plan revisions for the review and permitting of sources of air pollutant emissions in nonattainment areas. Included in the plan are Missouri regulations 10 CSR 10-6.020, Definitions, and 10 CFR 10-6.060, Permits Required, as amended, in part, in subsequent submittals, which are approved as meeting the requirements of sections 172(b)(6), 172(b)(11)(A) and 173.
(19) On July 2, 1979, the Missouri Department of Natural Resources submitted the variance for the University of Missouri power plant.
(20) On March 11, 1977 the Missouri Department of Natural Resources submitted a variance for Noranda Aluminum.
(21) On June 25, 1979 the Missouri Department of Natural Resources submitted a variance for Associated Electric Cooperative in New Madrid.
(22) On April 25, 1979, the Missouri Department of Natural Resources submitted the variance for the Union Electric Company's Meramec power plant.
(23) Revisions to Rule 10 CSR 10-2.260 Control of Petroleum Liquid Storage, Loading and Transfer (Kansas City), submitted on September 5, 1980, amending the vapor pressure limit in Section 2(A) and amending the limit on gasoline loading in Section 3(B)(1), are approved as RACT.
(24) A schedule for an inspection and maintenance program in St. Louis and a commitment by the East-West Gateway Coordinating Council regarding difficult transportation control measures, submitted on September 9, 1980.
(25) On September 5, 1980, the State of Missouri submitted new regulations and amendments to existing regulations to control emissions of volatile organic compounds in the St. Louis and Kansas City ozone nonattainment areas. Included in the plan revision are the following approved regulations as amended, in part, in subsequent submittals:
(i) Amendments to Rule 10 CSR 10-2.230 and to Rule 10 CSR 10-5.330, Control of Emissions from Industrial Surface Coating Operations, are approved as RACT;
(ii) Amendments to Rule 10 CSR 10-2.260 and to Rule 10 CSR 10-5.220, Control of Petroleum Liquid Storage, Loading and Transfer, are approved as RACT;
(iii) Amendments to Rule 10 CSR 10-6.020, Definitions, and to Rule 10 CSR 10-6.030, Sampling Methods for Air Pollution Sources, and to Rule 10 CSR 10-6.040, Reference Methods, are approved as RACT;
(iv) Rule 10 CSR 10-2.280 and Rule 10 CSR 10-5.320, Control of Emissions from Perchloroethylene Dry Cleaning Installations, are approved as RACT;
(v) Rule 10 CSR 10-2.290, Control of Emissions from Rotogravure and Flexographic Printing Facilities, is approved as RACT;
(vi) Rule 10 CSR 10-5.350, Control of Emissions from the Manufacture of Synthesized Pharmaceutical Products, is approved as RACT;
(vii) Rule 10 CSR 10-5.340, Control of Emissions from Rotogravure and Flexographic Printing Facilities is approved as RACT.
(26) On September 2, 1980, the Missouri Department of Natural Resources submitted the State Implementation Plan for Lead. On February 11 and 13, 1981, the Missouri Department of Natural Resources submitted two letters containing additional information concerning the State Implementation Plan for Lead.
(27) On September 5, 1980, the state of Missouri submitted a plan revision which involved provisions for start-up, shutdown, and malfunction conditions. Included in the plan are new Missouri Rule 10 CSR 10-6.050, Start-up Shutdown, and MalfunctionConditions; and revisions to Rule 10 CSR 10-6.020, Defintions and Amended Start-up, Shutdown and Malfunction Provisions in Rules 10 CSR 10-2.030, 10-3.050, 10-3.060, 10-3.080, 10-4.030, 10-4.040, and 10-5.050.
(28) Revisions to Rule 10 CSR 10-6.060 Permits Required, submitted on April 7, 1981.
(29) A revision to Rule 10 CSR 10-5.220 Control of Petroleum Liquid Storage, Loading and Transfer (St. Louis), submitted on April 14, 1981, amending the emission limit in Section 3, is approved as RACT.
(30) A report on the recommended type of I/M program, stringency factor, vehicle test mix, and program resources and justification, submitted on December 16, 1980, is approved as meeting the applicable condition on the SIP. No action is being taken with respect to the approvability of the specific recommendation sin the report.
(31) A report from the East-West Gateway Coordinating Council outlining commitments to transportation control measures, an analysis of those measures, and the results of the carbon monoxide dispersion modeling, submitted on February 12 and April 28, 1981, is approved as meeting the applicable condition on the SIP.
(32) A variance from Missouri Rule 10 CSR 10-3.050 Restriction of Emission of Particulate Matter From Industrial Processes, for St. Joe Minerals Corporation, Pea Ridge Iron Ore facility, was submitted by the Missouri Department of Natural Resources on May 6, 1981 with supplementary information submitted on June 22 and July 28, 1981.
(33) On September 5, 1980, the Missouri Department of Natural Resources submitted a revision of Missouri Rule 10 CSR 10-3.050, Restriction of Emission of Particulate Matter from Industrial Processes, which exempts existing Missouri type charcoal kilns from the rule.
(34) A variance from Missouri Rules 10 CSR 10-3.060, Maximum Allowable Emissions of Particulate Matter from Fuel Burning Equipment Used for Indirect Heating, and 10 CSR 10-3.080, Restriction of Emission of Visible Air Contaminants, was submitted by the Missouri Department of Natural Resources on August 12, 1981.
(35) A variance from Missouri Rule 10 CSR 10-2.260, Control of Petroleum Liquid Storage, Loading and Transfer for the Kansas City Metropolitan Area, was submitted by the Missouri Department of Natural Resources on June 11, 1981.
(36) Revisions to Rule 10 CSR 10-5.340, Control of Emissions from Rotogravure and Flexographic Printing Facilities, submitted on April 15, 1982, are approved as RACT.
(37) On April 15, 1982, the State of Missouri submitted a new Rule 10 CSR 10-6.060, Permits Required, and Amendments to Rule 10 CSR 10.6020, Definitions, involving the review and permitting of new sources of air pollution. Included in the plan are provisions relating to the attainment area (PSD) new source review. The plan also includes new source review provisions of nonattainment areas in the State.
(38) Revisions to Rules 10 CSR 10-2.280 (Kansas City) and 10 CSR 10-5.320 (St. Louis), both entitled Control of Emissions from Perchloroethylene Dry Cleaning Installations, and 10 CSR 10-5.290, More Restrictive Emission Limitations for Sulfur Dioxide and Particulate Matter in the South St. Louis Area, submitted on July 13, 1982, are approved.
(39) [Reserved]
(40) The 1982 carbon monoxide and ozone state implementation plan revisions were submitted by the Department of Natural Resources on December 23, 1982. A revised version of the 1982 carbon monoxide and ozone plan was submitted by the Department of Natural Resources on August 24, 1983. This version contained updated inventories, attainment demonstrations and schedules to adopt rules. The submission included new rule 10 CSR 10-5.360, Control of Emissions from Polyethylene Bag Sealing Operations. (No action was taken with respect to provisions dealing with control strategy demonstration, reasonable further progress and inspection and maintenance of motor vehicles.)
(41) Revised rule 10 CSR 10-1.010, General Organization, was submitted by the Missouri Department of Natural Resources on December 30, 1982.
(42) [Reserved]
(43) On March 26, 1984, the Missouri Department of Natural Resources submitted a revision to the September 2, 1980, lead State Implementation Plan pertaining to item 4 of the consent order for the St. Joe Lead Company. The revision consists of a substitution of equivalent control measures for item 4.
(44) A variance from Missouri Rule 10 CSR 10-3.050, Restriction of Emission of Particulate Matter from Industrial Processes, for the St. Joe Minerals Corporation, Pea Ridge Iron Ore facility, was submitted by the Missouri Department of Natural Resources on July 1, 1983.
(45) The Missouri Department of Natural Resources submitted revisions to regulations 10 CSR 10-2.100, 3.030, 4.090, and 5.070 requiring operating permits for open burning of untreated wood waste at solid waste disposal and processing installations effective April 12, 1984.
(46) On June 6, 1984, the Missouri Department of Natural Resources submitted the Air Quality Monitoring State Implementation Plan.
(47) In a letter dated August 14, 1984, the Missouri Department of Natural Resources submitted the rules, 10 CSR 10-6.030, Sampling Methods for Air Pollution Sources, and 10 CSR 10-6.040, Reference Methods.
(48) Revised rules 10 CSR 10-2.040, 3.060, 4.040 and 5.030 all entitled “Maximum Allowable Emission of Particulate Matter from Fuel Burning Equipment Used for Indirect Heating” were submitted September 24, 1984, by the Department of Natural Resources.
(49) On October 5, 1984, the Missouri Department of Natural Resources submitted a revision to the September 2, 1980, lead State Implementation Plan pertaining to item 6 of the Consent Order for the AMAX Lead Company. The revision consists of a substitution of equivalent control measures for item 6.
(50) The Missouri Department of Natural Resources submitted an amendment to Rule 10 CSR 10-5.330 “Control of Emissions from Industrial Surface Coating Operations,” limiting emissions from surface coating of plastic parts and new Rule 10 CSR 10-5.370 “Control of Emissions from the Application of Deadeners and Adhesives” on January 24, 1984; and new Rule 10 CSR 10-5.390, “Control of Emissions from Manufacture of Paints, Varnishes, Lacquers, Enamels and Other Allied Surface Coating Products” and an amendment to 10 CSR 10-6.020, “Definitions” on April 10, 1984. (Approval action was deferred on 10 CSR 10-5.370.)
(51) The motor vehicle inspection and maintenance program for the St. Louis area was submitted August 27, 1984, by the Department of Natural Resources.
(i) Incorporation by reference.
(A) Amendment to Regulations 10 CSR 10-5.380, “Motor Vehicle Emissions Inspections”, published in the Missouri Register January 3, 1982;
(B) Missouri Revised Statutes, Sections 307.350 through 307.395, “Motor Vehicle Safety Inspection”, as revised September 1983;
(C) Regulations 11 CSR 50-2.010 through 11 CSR 50-2.410, “Missouri Motor Vehicle Inspection Regulations”, as revised July 1, 1982.
(ii) Additional material.
(A) I/M Implementation Schedule.
(B) Highway Patrol Forms.
(C) Missouri Certified Emission Analyzers.
(D) Missouri Department of Revenue Policy.
(E) Highway Patrol QC Manual.
(F) EPA Approval of RACT Compliance.
(G) Public Awareness Materials.
(52) [Reserved]
(53) A rule requiring sources to keep records and report data and requiring emission data to be made public was submitted January 22, 1985, by the Department of Natural Resources. This rule replaces previous rules 10 CSR 10-2.130, 3.130, 4.120, and 5.210, all entitled “Submission of Emission Information” which were approved as parts of the State Implementation Plan; and previous rules 10 CSR 10-2.180, 3.120, 4.170, and 5.270, all entitled “Public Availability of Emission Data” which were not approved prior to the submission of this replacement rule.
(i) Incorporation by reference. A new regulation 10 CSR 10-6.110 published in the Missouri Register November 1, 1984.
(54) A new rule, Controlling Emissions During Episodes of High Air Pollution Potential, was submitted by the Department of Natural Resources on January 22, 1985.
(i) Incorporation by reference. 10 CSR 10-6.130, Controlling Emissions During Episodes of High Air Pollution Potential, adopted by the Missouri Air Conservation Commission and effective on October 11, 1984.
(ii) Additional material. The State has rescinded rules 10 CSR 10-2.170, 3.110, 4.160, and 5.260, all entitled “Rules for Controlling Emission During Periods of High Air Pollution Potential.”
(55) [Reserved]
(56) The Missouri Department of Natural Resources submitted the Protection of Visibility Plan, 1985, on May 3, 1985.
(i) Incorporation by reference.
(A) Amendments to Missouri Rule 10 CSR 10-6.020, Definitions, and Rule 10 CSR 10-6.060, Permits Required. These Amendments were adopted by the Missouri Air Conservation Commission and became effective on May 11, 1985.
(ii) Additional material.
(A) Narrative description of visibility new source review program for Class I areas in Missouri.
(B) Visibility monitoring plan for Class I areas in Missouri.
(57) On July 1, 1985, the Missouri Department of Natural Resources submitted amendments to Rules 10 CSR 10-5.220 for the St. Louis Metropolitan Area, and 10 CSR 10-2.260 for the Kansas City Metropolitan Area. The amendments require bulk gasoline plants to be equipped with a vapor recovery system if their monthly throughput is greater than the exemption level.
(i) Incorporation by reference.
(A) 10 CSR 10-5.220, and 10 CSR 10-2.260, Control of Emissions from Petroleum Liquid Storage, Loading, and Transfer, as published in the Missouri Register on May 1, 1985.
(58) A plan revision demonstrating that the ozone standard will be attained in the St. Louis ozone nonattainment area by December 31, 1987, was submitted by the Department of Natural Resources on August 1, 1985.
(i) Incorporation by reference.
(A) An agreement and variance modification order dated July 18, 1985, signed by the Missouri Air Conservation Commission and the General Motors (GM) Corporation requiring that the GM St. Louis assembly plant meet interim emission limitations and comply with the SIP by shutdown by December 31, 1987.
(ii) Additional material.
(A) A revised and corrected emission inventory for base year 1980.
(B) A revised projected year 1987 inventory demonstrating that the additional emission reductions from two new regulations and one plant shutdown, in addition to reductions already required, will be adequate to reduce ambient ozone concentrations to the National Ambient Air Quality Standard for ozone.
(59) A new rule, Control of Emissions from the Production of Maleic Anhydride, was submitted by the Department of Natural Resources on January 21, 1986.
(i) Incorporation by reference.
(A) 10 CSR 10-5.400, Control of Emissions from the Production of Maleic Anhydride, adopted by the Missouri Air Conservation Commission and effective on October 26, 1985.
(60) A plan revision to correct motor vehicle inspection and maintenance testing deficiencies was submitted by the Department of Natural Resources on December 29, 1987.
(i) Incorporation by reference.
(A) Regulations 11 CSR 50-2.370 and 11 CSR 50-2.400, effective June 25, 1987.
(61) On June 9, 1986, the state of Missouri submitted an amendment to Rule 10 CSR 10-5.220, Control of Petroleum Liquid Storage, Loading, and Transfer. This amendment requires the control of volatile organic compound emissions from the refueling of motor vehicles in the St. Louis Metropolitan Area.
(i) Incorporation by reference.
(A) 10 CSR 10-5.220, Control of Petroleum Liquid Storage, Loading, and Transfer, revised paragraphs 4, 5, 6, 7, 8, and 9, published in the Missouri Register on May 1, 1985.
(62) A new rule, Control of Equipment Leaks from Synthetic Organic Chemical and Polymer Manufacturing Plants, was submitted by the Department of Natural Resources on November 19, 1986.
(i) Incorporation by reference, 10 CSR 10-5.420, Control of Equipment Leaks from Synthetic Organic Chemical and Polymer Manufacturing Plants, effective on September 26, 1986.
(63) An amendment to the rule, Restriction of Emissions of Sulfur Compounds, was submitted by the Department of Natural Resources on November 19, 1986.
(i) Incorporation by reference.
(A) Amended Regulation 10 CSR 10-3.100, Restriction of Emission of Sulfur Compounds adopted October 16, 1986, and effective on November 28, 1986.
(64) A variance from Missouri Rule 10 CSR 10-3.050, Restriction of Emission of Particulate Matter from Industrial Processes, for the St. Joe Minerals Corporation, Pea Ridge Iron Ore facility, was submitted by the Missouri Department of Natural Resources on October 22, 1987.
(i) Incorporation by reference.
(A) Variance order modification dated May 21, 1987, issued to St. Joe Minerals Corporation allowing certain equipment at its Pea Ridge Iron Ore facility to operate beyond the limitations specified in Rule 10 CSR 10-3.050, Restriction of emissions of Particulate Matter from Industrial Processes, for outstate Missouri area, effective May 21, 1987.
(65) Revised regulations for the control of volatile organic compound emissions in the Kansas City area were submitted by the Missouri Department of Natural Resources on May 21, 1986, and December 18, 1987. The May 21, 1986, submittal also included anozone attainment demonstration for Kansas City, which will be addressed in a future action.
(i) Incorporation by reference.
(A) Revision to Rule 10 CSR 10-2.260, Control of Emissions from Petroleum Liquid Storage, Loading, and Transfer, effective May 29, 1986, with amendments effective December 24, 1987.
(B) New Rule 10 CSR 10-2.300, Control of Emissions from the Manufacturing of Paints, Varnishes, Lacquers, Enamels, and Other Allied Surface Coating Products, effective December 12, 1987.
(C) New Rules 10 CSR 10-2.310, Control of Emissions from the Application of Automotive Underbody Deadeners, and 10 CSR 10-2.320, Control of Emissions from Production of Pesticides and Herbicides, effective November 23, 1987.
(D) Rescinded Rules 10 CSR 10-2.240, Control of Emissions of Volatile Organic Compounds from Petroleum Refinery Equipment, and 10 CSR 10-2.250, Control of Volatile Leaks from Petroleum Refinery Equipment, effective November 23, 1987.
(E) Revision to Rule 10 CSR 10-6.030, Sampling Methods for Air Pollution Sources, effective November 23, 1987, with amendments effective December 24, 1987.
(F) Revision to Rule 10 CSR 10-2.210, Control of Emissions from Solvent Metal Cleaning, effective December 12, 1987.
(G) Revisions to Rules 10 CSR 10-2.290, Control of Emissions from Rotogravure and Flexographic Printing Facilities, and 10 CSR 10-6.020, Definitions, effective December 24, 1987.
(66) The Missouri Department of Natural Resources submitted revisions to its state implementation plan to incorporate PM 10 on March 29, 1988, May 12, 1988, and June 15, 1988.
(i) Incorporation by reference.
(A) Revisions to the following Missouri air pollution rules:
These rules were published in the Missouri Register on April 18, 1988, and became effective April 28, 1988.
(ii) Additional material.
(A) A revision to the Missouri Monitoring Plan was submitted March 29, 1988.
(B) A narrative description of the PM 10 SIP for the state of Missouri was submitted June 15, 1988.
(67) Plan revisions were submitted by the Missouri Department of Natural Resources on August 18, 1986, and October 18, 1988, which implement EPA's July 8, 1985, revised stack height requirements.
(i) Incorporation by reference.
(A) Revisions to rules 10 C.S.R. 10-6.020, Definitions, and 10 CSR 10-6.060, Permits Required, effective May 11, 1986.
(B) New rule 10 C.S.R. 10-6.140, Restriction of Emissions Credit for Reduced Pollutant Concentrations from the Use of Dispersion Techniques, effective May 11, 1986.
(C) Revisions to rule 10 CSR 10-6.020, Definitions, effective August 25, 1988.
(68) Revised regulations applicable to air quality models were submitted by the Missouri Department of Natural Resources on October 18, 1988.
(i) Incorporation by reference.
(A) Revision of rule 10 CSR 10-6.060 “Permits Required,” effective on September 29, 1988.
(69) A plan revision to change the construction permit fees was submitted by the Department of Natural Resources on January 24, 1989, and September 27, 1989.
(i) Incorporation by reference.
(A) Revision to 10 CSR 10-6.060, Permits Required, amended December 19, 1988, effective January 1, 1989.
(ii) Additional material.
(A) Chapter 643 RSMo (House Bill Number 1187) passed by the General Assembly of the state of Missouri in 1988.
(70) The Missouri Department of Natural Resources submitted amendments to Rule 10 CSR 10-2.230 on December 18, 1987, and December 19, 1988. The rule controls volatile organic compound emissions from industrial surface coating facilities in the Kansas City area.
(i) Incorporation by reference.
(A) Revision to Rule 10 CSR 10-2.230, Control of Emissions from Industrial Surface Coating Operations, effective December 24, 1987, with amendments effective November 24, 1988.
(71) Revisions to regulations for controlling volatile organic compound emissions in the St. Louis area were submitted by the Missouri Department of Natural Resources on June 14, 1985; November 19, 1986; and March 30, 1989.
(i) Incorporation by reference.
(A) New Rule 10 CSR 10-5.410, Control of Emissions from the Manufacture of Polystyrene Resin, effective May 11, 1985, with amendments effective September 26, 1986, and March 11, 1989.
(B) Revisions to Rules 10 CSR 10-5.220, Control of Petroleum Liquid Storage, Loading and Transfer; 10 CSR 10-5.300, Control of Emissions from Solvent Metal Cleaning; 10 CSR 10-5.310, Liquefied Cutback Asphalt Paving Restricted; 10 CSR 10-5.320, Control of Emissions from Perchloroethylene Dry Cleaning Installations; 10 CSR 10-5.340, Control of Emissions from Rotogravure and Flexographic Printing Facilities; 10 CSR 10-5.350, Control of Emissions of Synthesized Pharmaceutical Products; 10 CSR 10-5.360, Control of Emissions from Polyethylene Bag Sealing Operations; 10 CSR 10-5.370, Control of Emissions from the Application of Deadeners and Adhesives; 10 CSR 10-5.390, Control of Emissions from the Manufacturing of Paints, Varnishes, Lacquers, Enamels, and Other Allied Surface Coating Products; 10 CSR 10-5.420, Control of Equipment Leaks from Synthetic Organic Chemical and Polymer Manufacturing Plants; and 10 CSR 6.020, Definitions; effective March 11, 1989.
(C) Rescinded Rule 10 CSR 10-5.400, Control of Emissions from Production of Maleic Anhydride, effective March 11, 1989.
(72) The Missouri Department of Natural Resources submitted new rule 10 CSR 10-5.330, Control of Emissions from Industrial Surface Coating Operations, and amendments to rule 10 CSR 10-6.020, Definitions, on January 11, 1990.
(i) Incorporation by reference.
(A) New rule 10 CSR 10-5.330, Control of Emissions from Industrial Surface Coating Operations, effective November 26, 1989.
(B) Rescinded rule 10 CSR 10-5.330, Control of Emissions from Industrial Surface Coating Operations, effective November 26, 1989.
(C) Revisions to rule 10 CSR 10-6.020, Definitions, effective November 26, 1989.
(73) A rule revision to establish gasoline tank truck certification requirements in ozone nonattainment areas was submitted by the Department of Natural Resources on July 17, 1990.
(i) Incorporation by reference.
(A) Revision to rule 10 CSR 10-2.260 and 10 CSR 10-5.220 both titled “Control of Petroleum Liquid Storage, Loading, and Transfer” effective May 24, 1990.
(74) Revisions to the circumvention plan submitted by the Missouri Department of Natural Resources on September 6, 1990.
(i) Incorporation by reference.
(A) Rule at 10 CSR 10-6.150, Circumvention, effective November 30, 1990.
(B) Rescission of rules 10 CSR 10-2.140, Circumvention; CSR 10-4.130, Circumvention; and 10 CSR 10-5.230, Circumvention, effective September 28, 1990.
(75) Plan revisions were submitted by the Missouri Department of Natural Resources on September 25, 1990, which implement EPA's October 17, 1988, PSD NO X requirements.
(i) Incorporation by reference
(A) Revisions to rules 10 CSR 10-6.020 “Definitions” and 10 CSR 10-6.060 “Permits Required” were adopted by the Missouri Air Conservation Commission on May 14, 1990, and became effective May 24, 1990.
(ii) Additional Information
(A) Letter from the state dated November 30, 1990, pertaining to NO X rules and analysis which certifies that the material was adopted by the state on May 24, 1990.
(76) In submittals dated September 6, 1990, and May 8, 1991, the Missouri Department of Natural Resources submitted a lead NAAQS attainment plan for the Doe Run Herculaneum primary lead smelter. Although Missouri rule 10 CSR 10-6.120 contains requirements which apply statewide to primary lead smelting operations, EPA takes action on this rule only insofar as it pertains to the Doe Run Herculaneum facility. Plan revisions to address the other lead smelters in the state are under development.
(i) Incorporation by reference.
(A) New rule 10 CSR 10-6.120, Restriction of Emissions of Lead from Primary Lead Smelter-Refinery Installations, effective December 29, 1988, with amendments effective March 14, 1991.
(B) Consent order, entered into between the Doe Run Company and the Missouri Department of Natural Resources, dated March 9, 1990.
(C) Supplemental consent order, signed by the Doe Run Company on July 26, 1990, and by the Missouri Department of Natural Resources on August 17, 1990.
(ii) Additional material.
(A) Narrative SIP material, submitted on September 9, 1990. This submittal includes the emissions inventory and attainment demonstration.
(B) The Doe Run Herculaneum Work Practice Manual was submitted on May 8, 1991. In the May 8, 1991, submittal letter, the state agreed that any subsequent changes to the work practice manual would be submitted to EPA as SIP revisions.
(77) Revisions to the state implementation plan for the Kansas City metropolitan area were submitted by the Director of the Missouri Department of Natural Resources on October 9, 1991. Revisions include a maintenance plan which demonstrates continued attainment of the NAAQS for ozone through the year 2002. Rule revisions were also submitted on October 9, 1991.
(i) Incorporation by reference.
(A) Revised regulations 10 CSR 10-6.020, Definitions, and 10 CSR 10-2.220, Liquefied Cutback Asphalt Paving Restricted, effective August 30, 1991; and new regulation 10 CSR 10-2.340, Control of Emissions from Lithographic Printing Facilities, effective December 9, 1991.
(ii) Additional material.
(A) State of Missouri Implementation Plan, Kansas City Metropolitan Area Maintenance Provisions, October 1991.
(78) The Missouri Department of Natural Resources submitted new rule 10 CSR 10-6.180, Measurement of Emissions of Air Contaminants, on March 4, 1991.
(i) Incorporation by reference.
(A) New rule 10 CSR 10-6.180 entitled “Measurement of Emissions of Air Contaminants” published November 19, 1990, effective December 31, 1990.
(79) The Missouri Department of Natural Resources submitted an amendment on March 19, 1992, to add sampling methods to rule 10 CSR 10-6.030 “Sampling Methods for Air Pollution Sources.” On November 20, 1991, Missouri submitted administrative amendments to rule 10 CSR 10-6.030 which renumber and reorganize sections within that rule. Rules which reference the renumbered sections of 10 CSR 10-6.030 were also administratively amended and submitted.
(i) Incorporation by reference.
(A) Revised regulation 10 CSR 10-6.030 “Sampling Methods for Air Pollution Sources” effective September 30, 1991.
(B) Administrative amendments to the sampling citations in the following rules which are affected by the administrative amendments to 10 CSR 10-6.030: 10 CSR 10-2.210, effective December 12, 1987; 10 CSR 10-2.230, effective November 24, 1988; 10 CSR 10-2.260, effective May 24, 1990; 10 CSR 10-2.280, effective May 13, 1982; 10 CSR 10-2.290, effective December 24, 1987; 10 CSR 10-2.300, effective December 12, 1987; 10 CSR 10-2.310, effective November 23, 1987; 10 CSR 10-2.320, effective November 23, 1987; 10 CSR 10-3.160, effective December 11, 1987; 10 CSR 10-5.220, effective May 24, 1990; 10 CSR 10-5.300, effective March 11, 1989; 10 CSR 10-5.320, effective March 11, 1989; 10 CSR 10-5.330, effective November 26, 1989; 10 CSR 10-5.350, effective March 11, 1989; 10 CSR 10-5.360, effective March 11, 1989; 10 CSR 10-5.370, effective March 11, 1989; 10 CSR 10-5.390, effective March 11, 1989; 10 CSR 10-5.410, effective March 11, 1989; 10 CSR 10-6.090, effective August 13, 1981; and 10 CSR 10-6.120, effective March 14, 1991.
(80) On June 28, 1991, the Missouri Department of Natural Resources (MDNR) submitted revisions to the Missouri State Implementation Plan which pertain to the St. Louis vehicle inspection and maintenance program. The Missouri rules contain requirements which apply to both safety and emission testing; EPA takes action on these rules only insofar as they pertain to emissions testing.
(i) Incorporation by reference.
(A) New rules 11 CSR 50-2.401, General Specifications; 11 CSR 50-2.402, Missouri Analyzer System (MAS) Software Functions; 11 CSR 50-2.403, MAS Display and Program Requirements; 11 CSR 50-2.405, Vehicle Inspection Certificate, Vehicle Inspection Report and Printer Function Specifications; 11 CSR 50-2.406, Technical Specifications for the MAS; and 11 CSR 50-2.407 Documentation, Logistics and Warranty Requirements; (appendix A, B, C), effective June 28, 1990.
(B) New rule 11 CSR 50-2.404, Test Record Specifications, effective September 28, 1990.
(C) Amended rules 11 CSR 50-2.370 Inspection Station Licensing; 11 CSR 50-2.410, Vehicles Failing Reinspection; and 11 CSR 50-2.420 Procedures for Conducting Only Emission Tests; effective December 31, 1990.
(D) Rescinded rule 11 CSR 50-2,400, Emission Test Procedures; effective December 31, 1990.
(81) The Missouri Department of Natural Resources submitted a rule action rescinding rules 10 CSR 10-2.120, 10 CSR 10-4.110, and 10-5.200, Measurement of Emissions of Air Contaminants for the Kansas City Metropolitan Area, Springfield-Greene County Area, and the St. Louis Metropolitan Area, respectively, on July 9, 1992.
(i) Incorporation by reference.
(A) Rescission of rules 10 CSR 10-2.120, 10 CSR 10-4.110, and 10 CSR 10-5.200 entitled “Measurement of Emissions of Air Contaminants” rescinded April 9, 1992.
(82) Revisions to the Missouri State Implementation Plan establishing a Small Business Stationary Source Technical and Environmental Compliance Assistance Program were submitted by the Director of the Missouri Department of Natural Resources on March 10, 1993.
(i) Incorporation by reference.
(A) Small Business Stationary Source Technical and Environmental Compliance Program dated November 1992 and adopted February 18, 1993.
(83) A revision to the Missouri State Implementation Plan (SIP) to incorporate the lead nonattainment areas into the existing new source review (NSR) program was submitted by the state on March 15, 1993. This revision changes the applicability requirements by changing the definition of nonattainment area in the state regulations to include lead nonattainment areas, and to delete the Kansas City area as a nonattainment area in light of its attainment of the ozone standard.
(i) Incorporation by reference.
(A) Revision to rule 10 C.S.R. 10-6.020, definitions, effective February 26, 1993.
(84) The Missouri Department of Natural Resources submitted rule revisions pertaining to rotogravure and flexographic printing facilities in Kansas City, Missouri, and St. Louis, Missouri; and an amendment to the sampling methods rule which adds a compliance test method for the capture efficiency of air pollution control devices. These amendments were submitted September 16 and September 23, 1992.
(i) Incorporation by reference.
(A) Revised regulations 10 CSR 10-2.290 (except section (6), Compliance Dates) and 10 CSR 10-5.340 (except section (6), Compliance Dates), both entitled Control of Emissions from Rotogravure and Flexographic Printing Facilities, effective February 6, 1992.
(B) Revised regulation 10 CSR 10-6.030 (section (20)), effective April 9, 1992.
(85) [Reserved]
(86) A revision to the Missouri SIP to revise the Missouri Part D new source review rules, update and add numerous definitions, revise the maximum allowable increase for particulate matter under the requirements for prevention of significant deterioration, address emission statements under Title I of the CAA, and generally enhance the SIP.
(i) Incorporation by reference.
(A) Revision to rules 10 CSR 10-6.020, Definitions and Common Reference Tables, effective August 30, 1995; 10 CSR 10-6.060, Construction Permits Required, effective August 30, 1995; 10 CSR 10-6.110, Submission of Emission Data, Emission Fees, and Process Information, except section 5, effective May 9, 1994; and 10 CSR 10-6.210, Confidential Information, effective May 9, 1994.
(87) In submittals dated July 2, 1993; June 30, 1994; and November 23, 1994, MDNR submitted an SIP to satisfy Federal requirements for an approvable nonattainment area lead SIP for the Doe Run primary smelter in Herculaneum, Missouri. Although Missouri rule 10 CSR 10-6.120 contains requirements which apply statewide to primary lead smelting operations, EPA takes action on this rule only insofar as it pertains to the Doe Run Herculaneum facility. Plan revisions to address the other lead smelters in the state are under development.
(i) Incorporation by reference.
(A) Revised regulation 10 CSR 10-6.120 (section (1), section (2)(B), section (3)) entitled Restriction of Emissions of Lead From Primary Lead Smelter-Refinery Installations, effective August 28, 1994.
(B) Consent Order, entered into between the Doe Run Company and MDNR, dated July 2, 1993.
(C) Consent Order amendment, signed by the Doe Run Company on March 31, 1994, and by MDNR on April 28, 1994.
(D) Consent Order amendment, signed by the Doe Run Company on September 6, 1994, and by MDNR on November 23, 1994.
(ii) Additional material.
(A) Revisions to the Doe Run Herculaneum Work Practice Manual submitted on July 2, 1993.
(B) Revisions to the Doe Run Herculaneum Work Practice Manual submitted on June 30, 1994.
(88) This revision submitted by the Missouri Department of Natural Resources on March 31, 1994, relates to intermediate sources, and the EPA is not approving the basic operating permit program. This revision establishes a mechanism for creating federally enforceable limitations. Emission limitations and related provisions which are established in Missouri operating permits as federally enforceable conditions shall be enforceable by EPA. EPA reserves the right to deem permit conditions not federally enforceable. Such a determination will be made according to appropriate procedures and be based upon the permit, permit approval procedures, or permit requirements which do not conform with the operating permit program requirements or the requirements of EPA's underlying regulations.
(i) Incorporation by reference.
(A) 10 C.S.R. 10-6.065 (sections 1, 2, 3, 4(C)-(P), 5, and 7) Operating Permits, effective May 9, 1994.
(ii) Additional material.
(A) Letter from Missouri to EPA Region VII dated November 7, 1994, regarding how Missouri intends to satisfy the requirements set forth in the Clean Air Act Amendments at sections 112(l)(5)(A), (B), and (C).
(B) Two letters from Missouri to EPA Region VII dated October 3, 1994, and February 10, 1995, supplementing the November 7, 1994, letter and clarifying that Missouri does have adequate authority to limit potential-to-emit of hazardous air pollutants through the state operating permit program.
(89) In submittals dated July 2, 1993; June 30, 1994; and November 23, 1994, the Missouri Department of Natural Resources (MDNR) submitted a State Implementation Plan (SIP) to satisfy Federal requirements for an approvable nonattainment area lead SIP for the Doe Run primary and secondary smelter near Bixby, Missouri (Doe Run-Buick). Although Missouri rule 10 CSR 10-6.120 contains requirements which apply statewide to primary lead smelting operations, EPA takes action on this rule insofar as it pertains to the Doe Run-Buick facility. Plan revisions to address the other lead smelters in the state are under development.
(i) Incorporation by reference.
(A) Revised regulation 10 CSR 10-6.120 (section (2)(C), section (4)) entitled Restriction of Emissions of Lead from Primary Smelter-Refinery Installations, effective August 28, 1994.
(B) Consent Order, entered into between the Doe Run Company and MDNR, dated July 2, 1993.
(C) Consent Order amendment, signed by the Doe Run Company on August 30, 1994, and by MDNR on November 23, 1994.
(ii) Additional material.
(A) The Doe Run-Buick Work Practice Manual submitted on July 2, 1993. EPA approves the Work Practice manual with the understanding that any subsequent changes to the Work Practice Manual will be submitted as SIP revisions.
(B) Revisions to the Doe Run-Buick Work Practice Manual submitted on June 30, 1994.
(90)-(91) [Reserved]
(92) On February 14, 1995, the Missouri Department of Natural Resources submitted two new rules which pertain to transportation conformity in Kansas City and St. Louis.
(i) Incorporation by reference.
(A) New rule 10 CSR 10-2.390 (except section (20) Criteria and Procedures: Interim Period Reductions in Ozone Areas (TIP)) and 10 CSR 10-5.480 (except section (22) Criteria and Procedures: Interim Period Reductions in Ozone Areas (TIP)), both entitled Conformity to State Implementation Plans of Transportation Plans, Programs, and Projects Developed, Funded, or Approved Under Title 23 U.S.C. or the Federal Transit Act, effective May 28, 1995.
(ii) Additional material.
(A) Missouri's Air Pollution Control Plan, St. Louis Metropolitan Area Ozone and Carbon Monoxide Transportation Conformity, January 12, 1995.
(B) Missouri's Air Pollution Control Plan, Kansas City Metropolitan Area Ozone Transportation Conformity, January 12, 1995.
(C) Policy agreement, entered into between the Missouri Department of Natural Resources, the Mid-America Regional Council, and the Highway and Transportation Commission of the state of Missouri, dated August 31, 1993.
(D) Letter from the state of Missouri to EPA, dated December 7, 1995, in which the state commits to implementing its state rule consistent with the Federal Transportation Conformity rule, as amended on August 29, 1995, with regards to the granting of an NO X waiver and the NO X conformity requirements.
(93) On February 14, 1995, the Missouri Department of Natural Resources (MDNR) submitted a new rule which pertains to general conformity.
(i) Incorporation by reference.
(A) New rule 10 CSR 10-6.300, entitled Conformity of General Federal Actions to State Implementation Plans, effective May 28, 1995.
(94) On April 12, 1995, the Missouri Department of Natural Resources submitted an emissions inventory update to the Kansas City maintenance plan approved by EPA on June 23, 1992. The submittal also establishes a motor vehicle emissions budget for the purpose of fulfilling the requirements of the Federal Transportation Conformity rule.
(i) Incorporation by reference.
(A) Kansas City Ozone Maintenance SIP Revisions: Emission Inventories and Motor Vehicle Emissions Budgets, adopted by the Missouri Air Conservation Commission on March 30, 1995.
(95) Plan revisions were submitted by the Missouri Department of Natural Resources on August 14, 1996, which reduce lead emissions from the Asarco primary lead smelter located within the lead nonattainment area defined by the boundaries of the Liberty and Arcadia Townships located in Iron County, Missouri.
(i) Incorporation by reference.
(A) Rule 10 CSR 10-6.120, Restriction of Emissions of Lead From Primary Lead Smelter—Refinery Installations, except subsection 2(B) and 2(C), and section 4, effective June 30, 1996.
(B) Consent Decree Case Number CV596-98CC, STATE OF MISSOURI ex. rel. Jeremiah W. (Jay) Nixon and the Missouri Department of Natural Resources v. ASARCO, INC., Missouri Lead Division, effective July 30, 1996, with Exhibits A, C, D, E, F, and G.
(ii) Additional material.
(A) Narrative SIP material submitted on August 14, 1996. This submittal includes the emissions inventory and the attainment demonstration.
(96) Revisions to the Missouri SIP submitted by the Missouri Department of Natural Resources on March 13, 1996, and August 6, 1996, pertaining to its intermediate operating permit program. The EPA is not approving provisions of the rules which pertain to the basic operating permit program.
(i) Incorporation by reference.
(A) Regulations 10 C.S.R. 10-6.020, Definitions and Common Reference Tables, effective June 30, 1996; and 10 C.S.R. 10-6.065, Operating Permits, effective June 30, 1996, except sections (4)(A), (4)(B), and (4)(H).
(97) On November 20, 1996, the Missouri Department of Natural Resources (MDNR) submitted a revised rule which pertains to general conformity.
(i) Incorporation by reference.
(A) Rule 10 CSR 10-6.300, entitled Conformity of General Federal Actions to State Implementation Plans, effective September 30, 1996.
(98) Revision to the Missouri SIP submitted by the Missouri Department of Natural Resources on July 14, 1997.
(i) Incorporation by reference.
(A) Missouri Emergency Rule, 10 CSR 10-2.330, Control of Gasoline Reid Vapor Pressure, effective May 1, 1997, and expires October 27, 1997.
(99) Revisions to the ozone attainment plan were submitted by the Governor on February 1, 1996.
(i) Incorporation by reference.
(A) Missouri Rule 10 CSR 10-2.260, “Control of Petroleum Liquid Storage, Loading, and Transfer,” effective December 30, 1995.
(B) Missouri Rule 10 CSR 10-5.220, “Control of Petroleum Liquid Storage, Loading, and Transfer,” effective December 30, 1995.
(100) A revision to the Missouri SIP was submitted by the Missouri Department of Natural Resources on February 1, 1996, pertaining to Emission Data, Emission Fees, and Process Information.
(i) Incorporation by reference.
(A) Missouri Rule 10 CSR 10-6.110, “Emission Data, Emission Fees, and Process Information,” effective December 30, 1995.
(101) On January 10, 1997, and February 2, 1997, the Missouri Department of Natural Resources submitted revised rules pertaining to transportation conformity.
(i) Incorporation by reference.
(A) Regulation 10 CSR 10-2.390, entitled Conformity to State Implementation Plans of Transportation Plans, Programs, and Projects Developed, Funded or Approved Under Title 23 U.S.C. or the Federal Transit Act, effective December 30, 1996.
(B) Regulation 10 CSR 10-5.480, entitled Conformity to State Implementation Plans of Transportation Plans, Programs, and Projects Developed, Funded or Approved Under Title 23 U.S.C. or the Federal Transit Act, effective December 30, 1996.
(102) Revised regulations for the control of fugitive particulate matter emissions were submitted by the Missouri Department of Natural Resources (MDNR) on September 25, 1990, and on November 20, 1996.
(i) Incorporation by reference.
(A) Regulation 10 CSR 10-6.170, entitled Restriction of Particulate Matter Beyond the Premises of Origin, effective November 30, 1990, as amended October 30, 1996.
(B) Rescission of regulation 10 CSR 10-2.050, entitled Preventing Particulate Matter From Becoming Airborne, effective September 28, 1990.
(C) Rescission of regulation 10 CSR 10-3.070, entitled Restriction of Particulate Matter From Becoming Airborne, effective September 28, 1990.
(D) Rescission of regulation 10 CSR 10-4.050, entitled Preventing Particulate Matter From Becoming Airborne, effective September 28, 1990.
(E) Rescission of regulation 10 CSR 10-5.100, entitled Preventing Particulate Matter From Becoming Airborne, effective on September 28, 1990.
(ii) Additional material.
(A) Letter from Missouri submitted on February 24, 1997, pertaining to the submission of supplemental documentation.
(103) Revisions to the Missouri plan were submitted by the Governor on March 20, 1997.
(i) Incorporation by reference.
(A) St. Louis City Ordinance 59270, Section 4—Definitions, numbers 80. “Open Burning,” 100. “Refuse,” 108. “Salvage Operation,” and 126. “Trade Waste” only; and Section 12, effective October 23, 1984.
(B) St. Louis City Permit No. 96-10-084, issued to Washington University School of Medicine Medical Waste Incinerator, 500 S. Euclid Avenue, effective February 20, 1997.
(C) St. Louis City Permit No. 96-10-083, issued to Washington University School of Medicine Pathological Incinerator, 4566 Scott Avenue, effective February 20, 1997.
(D) St. Louis City Operating Permit, issued to St. Louis University Medical Center Medical Waste Incinerator, 3628 Rutger Avenue, effective August 3, 1992.
(E) Kansas City Air Quality Control Code C.S. No. 56726, Chapter 8, Sections: 8-2, definitions for “Open burning,” “Refuse,” “Salvage operation,” and “Trade waste”; and 8-4, only, effective August 2, 1984.
(F) Remove St. Louis City Ordinance 50163, effective June 11, 1968.
(G) Remove St. Louis City Ordinance 54699, effective March 27, 1967.
(H) Remove St. Louis County Air Pollution Control Code SLCRO, Title VI, Chapter 612, effective February 22, 1967.
(I) Remove Kansas City Air Pollution Control Code C.S. No. 36539, Chapter 18, except sections: 18.83—Definitions, subsections (13) “Incinerators” and (15) “Multiple Chamber Incinerators”; and 18.91—Incinerators, effective August 31, 1972.
(J) Remove City of Springfield Air Pollution Control Standard G.O. No. 1890, Chapter 2A, except sections: 2A-2—Definitions, the definitions for “Director of Health,” “Existing Equipment,” “Incinerator,” “Multiple-chamber incinerator,” “New equipment,” “Open burning,” “Particulate matter,” “Refuse,” and “Trade waste”; 2A-25; 2A-34; 2A-35; 2A-36; 2A-37; 2A-38; 2A-51; 2A-55; and 2A-56, effective October 12, 1969.
(104) [Reserved]
(105) Revision to the Missouri SIP submitted by the Missouri Department of Natural Resources on November 13, 1997.
(i) Incorporation by reference.
(A) Missouri Rule, 10 CSR 10-2.330, Control of Gasoline Reid Vapor Pressure, effective October 30, 1997.
(106) On December 17, 1996, the Missouri Department of Natural Resources submitted a revised rule pertaining to capture efficiency.
(i) Incorporation by reference.
(A) Revised regulation 10 CSR 10-6.030 entitled, “Sampling Methods for Air Pollution Sources,” effective November 30, 1996.
(107) New regulation for control of volatile organic emissions from Kansas City commercial bakeries submitted by the Missouri Department of Natural Resources March 13, 1996.
(i) Incorporation by reference.
(A) Rule 10 CSR 10-2.360 entitled “Control of Emissions from Bakery Ovens,” effective December 30, 1995.
(108) On August 12, 1997, the Missouri Department of Natural Resources (MDNR) submitted a new rule which consolidated the SO 2 rules into one and rescinded eight existing rules dealing with sulfur compounds.
(i) Incorporation by reference.
(A) Regulation 10 CSR 10-6.260, Restriction of Emission of Sulfur Compounds, except Section (4), Restriction of Concentration of Sulfur Compounds in the Ambient Air, and Section (3), Restriction of Concentration of Sulfur Compounds in Emissions, effective on August 30, 1996.
(B) Rescission of rules 10 CSR 10-2.160, Restriction of Emission of Sulfur Compounds; 10 CSR 10-2.200, Restriction of Emission of Sulfur Compounds From Indirect Heating Sources; 10 CSR 10-3.100, Restriction of Emission of Sulfur Compounds; 10 CSR 10-3.150, Restriction of Emission of Sulfur Compounds From Indirect Heating Sources; 10 CSR 10-4.150, Restriction of Emissions of Sulfur Compounds; 10 CSR 10-4.190, Restriction of Emission of Sulfur Compounds From Indirect Heating Sources; 10 CSR 10-5.110, Restrictions of Emission of Sulfur Dioxide for Use of Fuel; and 10 CSR 10-5.150, Emission of Certain Sulfur Compounds Restricted; effective July 30, 1997.
(109) This State Implementation Plan (SIP) revision submitted by the state of Missouri on July 10, 1996, broadens the current rule exceptions to include smoke-generating devices. This revision would allow smoke generators to be used for military and other types of training when operated under applicable requirements.
(i) Incorporation by reference.
(A) Regulation 10 CSR 10-3.080, “Restriction of Emission of Visible Air Contaminants,” effective on May 30, 1996.
(110) On May 28, 1998, the Missouri Department of Natural Resources submitted revisions to the construction permits rule.
(i) Incorporation by reference.
(A) Missouri Rule 10 CSR 10-6.060, “Construction Permits Required,” except Section (9), effective April 30, 1998.
(111) A revision submitted by the Governor's designee on July 30, 1998, that reduces air emissions from batch-type charcoal kilns throughout the state of Missouri.
(i) Incorporation by reference:
(A) New Missouri rule 10 CSR 10-6.330, Restriction of Emissions from Batch-Type Charcoal Kilns, effective July 30, 1998.
(112) Revisions submitted on November 13, 1998, and December 7, 1998, by the MDNR that modify Missouri's Out-state Open Burning Rule and add sampling methods to Missouri's Sampling Method Rule, respectively.
(i) Incorporation by reference:
(A) Revisions to Missouri rule 10 CSR 10-3.030 entitled “Open Burning Restrictions,” effective August 30, 1998.
(B) Revisions to Missouri rule 10 CSR 10-6.030 entitled “Sampling Methods for Air Pollution Sources,” effective November 30, 1998.
§ 52.1323   Approval status.
(a) With the exceptions set forth in this subpart, the Administrator approves Missouri's plans for the attainment and maintenance of the national standards. Continued satisfaction of the requirements of Part D for the ozone portion of the SIP depends on the adoption and submittal of RACT requirements by July 1, 1980, for the sources covered by CTGs issued between January 1978 and January 1979 and adoption and submittal by each successive January of Additional RACT requirements for sources covered by CTGs issued the previous January. New source review permits issued pursuant to section 173 of the Clean Air Act will not be deemed valid by EPA unless the provisions of Section V of the emission offset interpretive rule published on January 16, 1979 (44 FR 3274) are met.
(b) The Administrator approves Rule 10 CSR 10-2.290 as identified under § 52.1320, paragraph (c)(65), with the understanding that any alternative compliance plans issued under this rule must be approved by EPA as individual SIP revisions. In the absence of such approval, the enforceable requirements of the SIP would be the reduction requirements stated in the rule.
(c) The Administrator approves Rule 10 CSR 10-2.230 as identified under § 52.1320, paragraph (c)(70), with the understanding that any alternative compliance plans issued under this rule must be approved by EPA as individual SIP revisions. In the absence of such approval, the enforceable requirements of the SIP would be the emission limits stated in the rule.
(d) The Administrator approves Rule 10 CSR 10-5.340 as identified under § 52.1320, paragraph (c)(71), with the understanding that any alternative compliance plans issued under this rule must be approved as individual SIP revisions. In the absence of such approval, the enforceable requirements of the SIP would be the reduction requirements stated in the rule.
(e) The Administrator approves Rule 10 CSR 10-5.330 as identified under § 52.1320, paragraph (c)(72), under the following terms, to which the state of Missouri has agreed: Subsections (5)(B)3 and (7)(B) of the rule contain provisions whereby the director of the Missouri Air Pollution Control Program has discretion to establish compliance determination procedures and equivalent alternative emission limits for individual sources. Any such director discretion determinations under this rule must be submitted to EPA for approval as individual SIP revisions. In the absence of EPA approval, the enforceable requirements of the SIP are the applicable emission limit(s) in subsection (4)(B) and the compliance determination provisions stated in subsection(5)(B)1 or (5)(B)2.
(f) The Administrator approves Rule 10 CSR 10-6.120 as identified under § 52.1320(c)(76), under the following terms, to which the state of Missouri has agreed. Subparagraph (2)(B)2.B.(IV) contains a provision whereby the Director of the Missouri Department of Natural Resources has discretion to approve revisions to the Doe Run Herculaneum work practice manual. Any revisions to the work practice manual, pursuant to this rule, must be submitted to EPA for approval as an individual SIP revision. Thus, any existing federally approved work practices remain in effect, until such time that subsequent revisions are submitted to EPA and approved as SIP revisions.
(g) The Missouri portion of the Kansas City metropolitan area was designated as nonattainment for ozone in 40 CFR part 81. Therefore, the Administrator approves continuation of the 7.8 RVP limit as federally enforceable in the Kansas City metropolitan area, even after the area is redesignated to attainment, because of its nonattainment designation effective January 6, 1992. Also, the requirement for 7.8 psi RVP volatility is deemed necessary to ensure attainment and maintenance of the ozone standard as demonstrated by the emissions inventory projections (based on use of 7.8 psi RVP) in Missouri's ozone maintenance plan for the Kansas City metropolitan area.
(h) Missouri rule 10 CSR 10-6.300 was rescinded on September 15, 2022.
(i) Emission limitations and related provisions which are established in Missouri's operation permits as federally enforceable conditions shall be enforceable by EPA. EPA reserves the right to deem permit conditions not federally enforceable. Such a determination will be made according to appropriate procedures, and be based upon the permit, permit approval procedures, or permit requirements which do not conform with the operating permit program requirements or the requirements of EPA's underlying regulations.
(j) Missouri rule 10 CSR 10-6.300 was rescinded on September 15, 2022.
(k) The state of Missouri revised 10 CSR 10-2.390 for Kansas City and 10 CSR 10-5.480 for St. Louis to update the transportation conformity requirements contained in 40 CFR Part 51, Subpart T, effective November 14, 1995.
(l) The Administrator conditionally approves Missouri emergency rule 10 CSR 10-2.330 under § 52.1320(c)(98). Full approval is contingent on the state submitting the permanent rule, to the EPA, by November 30, 1997.
(m) The Administrator approves Missouri rule 10 CSR 10-2.330 under § 52.1320(c)(105). This fulfills the requirements of the conditional approval granted effective November 10, 1997, as published on October 9, 1997.
(n) Missouri rule 10 CSR 10-2.330 was rescinded on April 12, 2021.
(o) The Administrator conditionally approves the Missouri SIP revisions that address the requirements of RACT under the 8-hour ozone NAAQS under § 52.1320(c). Full approval is contingent on Missouri submitting RACT rules for inclusion into the Missouri SIP to address the Solvent Cleanup Operations CTG, to the EPA, no later than December 31, 2012.
(p) For the 2015 8-hour ozone NAAQS:
(1) Disapproval. Missouri state implementation plan (SIP) revision submitted on June 10, 2019, to address the Clean Air Act (CAA) infrastructure requirements of section 110(a)(2) for the 2015 8-hour ozone NAAQS, is disapproved for section 110(a)(2)(D)(i)(I) (prongs 1 and 2).
(2) [Reserved]
§ 52.1324   [Reserved]
§ 52.1325   Legal authority.
(a) [Reserved]
(b) The requirements of § 51.232(b) of this chapter are not met since the following deficiencies exist in local legal authority.
(1) St. Louis County Division of Air Pollution Control:
(i) Authority to require recordkeeping is lacking (§ 51.230(e) of this chapter).
(ii) Authority to make emission data available to the public is inadequate because section 612.350, St. Louis County Air Pollution Control Code, requires confidential treatment in certain circumstances if the data concern secret processes (§ 51.230(f) of this chapter).
(2) St. Louis City Division of Air Pollution Control:
(i) Authority to require recordkeeping is lacking (§ 51.230(e) of this chapter).
(ii) Authority to require reports on the nature and amounts of emissions from stationary sources is lacking (§ 51.230(e) of this chapter).
(iii) Authority to require installation, maintenance, and use of emission monitoring devices is lacking. Authority to make emission data available to the public is inadequate because Section 39 of Ordinance 54699 requires confidential treatment in certain circumstances if the data relate to production or sales figures or to processes or production unique to the owner or operator or would tend to affect adversely the competitive position of the owner or operator (§ 51.230(f) of this chapter).
(3) Kansas City Health Department:
(i) Authority to require recordkeeping is lacking (§ 51.230(e) of this chapter).
(4) Independence Health Department:
(i) Authority to require recordkeeping is lacking (§ 51.230(e) of this chapter).
(ii) Authority to make emission data available to the public is lacking since section 11.161 of the code of the city of Independence requires confidential treatment in certain circumstances if the data relate to secret processes or trade secrets affecting methods or results of manufacture (§ 51.230(f) of this chapter).
(5) Springfield Department of Health:
(i) Authority to abate emissions on an emergency basis is lacking (§ 51.230(c) of this chapter).
(ii) Authority to require recordkeeping is lacking (§ 51.230(e) of this chapter).
(iii) Authority to make emission data available to the public is inadequate because section 2A-42 of the Springfield City Code requires confidential treatment of such data in certain circumstances (§ 51.230(f) of this chapter).
(c) The provisions of § 51.230(d) of this chapter are not met since statutory, authority to prevent construction, modification, or operation of a facility, building, structure, or installation, or combination thereof, which indirectly results or may result in emissions of any air pollutant at any location which will prevent the maintenance of a national air quality standard is not adequate.
§ 52.1326   Interstate pollutant transport provisions; What are the FIP requirements for decreases in emissions of nitrogen oxides?
(a)(1) The owner and operator of each source and each unit located in the State of Missouri and for which requirements are set forth under the CSAPR NO X Annual Trading Program in subpart AAAAA of part 97 of this chapter must comply with such requirements. The obligation to comply with such requirements will be eliminated by the promulgation of an approval by the Administrator of a revision to Missouri's State Implementation Plan (SIP) as correcting the SIP's deficiency that is the basis for the CSAPR Federal Implementation Plan under § 52.38(a), except to the extent the Administrator's approval is partial or conditional.
(2) Notwithstanding the provisions of paragraph (a)(1) of this section, if, at the time of the approval of Missouri's SIP revision described in paragraph (a)(1) of this section, the Administrator has already started recording any allocations of CSAPR NO X Annual allowances under subpart AAAAA of part 97 of this chapter to units in the State for a control period in any year, the provisions of subpart AAAAA of part 97 of this chapter authorizing the Administrator to complete the allocation and recordation of CSAPR NO X Annual allowances to units in the State for each such control period shall continue to apply, unless provided otherwise by such approval of the State's SIP revision.
(b)(1) The owner and operator of each source and each unit located in the State of Missouri and for which requirements are set forth under the CSAPR NO X Ozone Season Group 1 Trading Program in subpart BBBBB of part 97 of this chapter must comply with such requirements with regard to emissions occurring in 2015 and 2016.
(2) The owner and operator of each source and each unit located in the State of Missouri and for which requirements are set forth under the CSAPR NO X Ozone Season Group 2 Trading Program in subpart EEEEE of part 97 of this chapter must comply with such requirements with regard to emissions occurring in 2017 through 2022. The obligation to comply with such requirements will be eliminated by the promulgation of an approval by the Administrator of a revision to Missouri's State Implementation Plan (SIP) as correcting the SIP's deficiency that is the basis for the CSAPR Federal Implementation Plan (FIP) under § 52.38(b)(1) and (b)(2)(ii), except to the extent the Administrator's approval is partial or conditional.
(3) The owner and operator of each source and each unit located in the State of Missouri and for which requirements are set forth under the CSAPR NO X Ozone Season Group 3 Trading Program in subpart GGGGG of part 97 of this chapter must comply with such requirements with regard to emissions occurring in 2023 and each subsequent year. The obligation to comply with such requirements will be eliminated by the promulgation of an approval by the Administrator of a revision to Missouri's State Implementation Plan (SIP) as correcting the SIP's deficiency that is the basis for the CSAPR Federal Implementation Plan (FIP) under § 52.38(b)(1) and (b)(2)(iii), except to the extent the Administrator's approval is partial or conditional.
(4) Notwithstanding the provisions of paragraphs (b)(2) and (3) of this section, if, at the time of the approval of Missouri's SIP revision described in paragraph (b)(2) or (3) of this section, the Administrator has already started recording any allocations of CSAPR NO X Ozone Season Group 2 allowances or CSAPR NO X Ozone Season Group 3 allowances under subpart EEEEE or GGGGG, respectively, of part 97 of this chapter to units in the State for a control period in any year, the provisions of such subpart authorizing the Administrator to complete the allocation and recordation of such allowances to such units for each such control period shall continue to apply, unless provided otherwise by such approval of the State's SIP revision.
(5) Notwithstanding the provisions of paragraph (b)(2) of this section, after 2022 the provisions of § 97.826(c) of this chapter (concerning the transfer of CSAPR NO X Ozone Season Group 2 allowances between certain accounts under common control), the provisions of § 97.826(e) of this chapter (concerning the conversion of amounts of unused CSAPR NO X Ozone Season Group 2 allowances allocated for control periods before 2023 to different amounts of CSAPR NO X Ozone Season Group 3 allowances), and the provisions of § 97.811(e) of this chapter (concerning the recall of CSAPR NO X Ozone Season Group 2 allowances equivalent in quantity and usability to all such allowances allocated to units in the State for control periods after 2022) shall continue to apply.
(6) Notwithstanding any other provision of this part, the effectiveness of paragraph (b)(3) of this section is stayed with regard to emissions occurring in 2023 and thereafter, provided that while such stay remains in effect, the provisions of paragraph (b)(2) of this section shall apply with regard to such emissions.
(c)(1) The owner and operator of each source located in the State of Missouri and for which requirements are set forth in § 52.40 and § 52.41, § 52.42, § 52.43, § 52.44, § 52.45, or § 52.46 must comply with such requirements with regard to emissions occurring in 2026 and each subsequent year.
(2) Notwithstanding any other provision of this part, the effectiveness of paragraph (c)(1) of this section is stayed.
§ 52.1327   Interstate pollutant transport provisions; What are the FIP requirements for decreases in emissions of sulfur dioxide?
(a) The owner and operator of each source and each unit located in the State of Missouri and for which requirements are set forth under the CSAPR SO 2 Group 1 Trading Program in subpart CCCCC of part 97 of this chapter must comply with such requirements. The obligation to comply with such requirements will be eliminated by the promulgation of an approval by the Administrator of a revision to Missouri's State Implementation Plan (SIP) as correcting the SIP's deficiency that is the basis for the CSAPR Federal Implementation Plan under § 52.39, except to the extent the Administrator's approval is partial or conditional.
(b) Notwithstanding the provisions of paragraph (a) of this section, if, at the time of the approval of Missouri's SIP revision described in paragraph (a) of this section, the Administrator has already started recording any allocations of CSAPR SO 2 Group 1 allowances under subpart CCCCC of part 97 of this chapter to units in the State for a control period in any year, the provisions of subpart CCCCC of part 97 of this chapter authorizing the Administrator to complete the allocation and recordation of CSAPR SO 2 Group 1 allowances to units in the State for each such control period shall continue to apply, unless provided otherwise by such approval of the State's SIP revision.
§§ 52.1328-52.1334   [Reserved]
§ 52.1335   Compliance schedules.
(a) The compliance schedule for the source identified below is approved as a revision to the plan pursuant to § 51.104 and subpart N of this chapter. All regulations cited are air pollution control regulations of the State, unless otherwise noted.
Missouri
(b) The compliance schedule submitted for the source identified below is disapproved as not meeting the requirements of subpart N of this chapter. All regulations cited are air pollution control regulations of the State, unless otherwise noted.
1 Regulation IV, air pollution control regulations for Kansas City metropolitan area.
Note: X = Air Pollution Control Regulations for the St. Louis Metropolitan Area.
§§ 52.1336-52.1338   [Reserved]
§ 52.1339   Visibility protection.
(a) The requirements of section 169A of the Clean Air Act are met because the plan includes measures for the protection visibility in mandatory Class I Federal areas. The Regional Haze Plan submitted by Missouri on August 5, 2009, and supplemented on January 30, 2012, in addition to the 5-year progress report submitted on September 5, 2014, and supplemented by state letter on July 31, 2017, contain fully approvable measures for meeting the requirements of the Regional Haze Rule.
(b) [Reserved]
§ 52.1340   Control strategy: Carbon monoxide.
Approval—A maintenance plan and redesignation request for the St. Louis, Missouri, area was submitted by the Director of the Missouri Department of Natural Resources on June 13, 1997. Additional information was received on June 15, 1998. The maintenance plan and redesignation request satisfy all applicable requirements of the Clean Air Act.
§ 52.1341   Control strategy: Particulate.
(a) Determination of attainment. EPA has determined, as of May 23, 2011, that the St. Louis (MO-IL) metropolitan 1997 PM 2.5 nonattainment area has attained the 1997 PM 2.5 NAAQS. This determination, in accordance with 40 CFR 51.1004(c), suspends the requirements for this area to submit an attainment demonstration, associated reasonably available control measures, reasonable further progress, contingency measures, and other plan elements related to attainment of the standards for as long as the area continues to meet the 1997 PM 2.5 NAAQS. In addition, based upon EPA's review of the air quality data for the three-year period 2007 to 2009, the St. Louis (MO-IL) PM 2.5 nonattainment area has attained the 1997 PM 2.5 NAAQS by the applicable attainment date of April 5, 2010.
(b) Redesignation to attainment. On September 1, 2011, and on March 31, 2014 and on September 17, 2014, Missouri submitted requests to redesignate the Missouri portion of the St. Louis MO-IL area to attainment of the 1997 Annual PM 2.5 standard. The Missouri portion of the St. Louis MO-IL area includes Jefferson, Franklin, St. Charles, and St. Louis Counties along with the City of St. Louis. As part of the redesignation request, the State submitted a plan for maintaining the 1997 Annual PM 2.5 standard through 2025 in the area as required by section 175A of the Clean Air Act.
§ 52.1342   Control strategy: Ozone.
(a) Determination of attainment. EPA has determined, as of June 9, 2011, that the St. Louis (MO-IL) metropolitan 1997 8-hour ozone nonattainment area has attained the 1997 8-hour ozone NAAQS. This determination, in accordance with 40 CFR 51.918, suspends the requirements for this area to submit an attainment demonstration, associated reasonably available control measures, reasonable further progress, contingency measures, and other plan elements related to attainment of the standards for as long as the area continues to meet the 1997 Ozone NAAQS. In addition, based upon EPA's review of the air quality data for the 3-year period 2007 to 2009, the St. Louis (MO-IL) ozone nonattainment area has attained the 1997 8-hour ozone NAAQS by the applicable attainment date of June 15, 2010.
(b) Approval. EPA is approving an April 20, 2011, request from the State of Missouri for a waiver from the Clean Air Act requirement for Oxides of Nitrogen (NO X ) Reasonably Available Control Technology (RACT) in the Missouri portion of the St. Louis (MO-IL) metropolitan 8-hour ozone nonattainment area for purposes of attaining the 1997 8-hour ozone National Ambient Air Quality Standard.
(c) On November 3, 2011 and April 29, 2014, Missouri submitted requests to redesignate the Missouri portion of the St. Louis MO-IL area to attainment of the 1997 8-hour ozone standard. The Missouri portion of the St. Louis MO-IL area includes Jefferson, Franklin, St. Charles, and St. Louis Counties along with the City of St. Louis. As part of the redesignation request, the State submitted a plan for maintaining the 1997 8-hour ozone standard through 2025 in the area as required by Section 175A of the Clean Air Act.
(d) Determination of attainment. As required by section 181(b)(2)(A) of the Clean Air Act, EPA has determined that the St. Louis, MO-IL marginal 2008 ozone nonattainment area has attained the NAAQS by the applicable attainment date of July 20, 2016.
(e) Redesignation to attainment. On September 12, 2016, and February 16, 2018, Missouri submitted requests to redesignate its portion of the St. Louis MO-IL area to attainment of the 2008 ozone standard. The Missouri portion of the St. Louis MO-IL area includes Jefferson, Franklin, St. Charles, and St. Louis Counties along with the City of St. Louis. As part of the redesignation request, the State submitted a plan for maintaining the 2008 ozone standard through 2030 in the area as required by section 175A of the Clean Air Act.
§ 52.1343   Control strategy: Sulfur dioxide.
(a) Determination of attainment. EPA has determined, as of September 13, 2017, that the Jefferson County 2010 SO 2 nonattainment has attained the 2010 SO 2 1-hr NAAQS. This determination suspends the requirements for this area to submit an attainment demonstration, associated reasonably available control measures, reasonable further progress, contingency measures, and other plan elements related to attainment of the standards for as long as the area continues to meet the 2010 SO 2 1-hr NAAQS.
(b) Determination of attainment. EPA has determined, as of July 9, 2020, that the Jackson County 2010 SO 2 nonattainment has attained the 2010 SO 2 1-hr NAAQS. This determination suspends the requirements for this area to submit an attainment demonstration, associated reasonably available control measures, reasonable further progress, contingency measures, and other plan elements related to attainment of the standards for as long as the area continues to meet the 2010 SO 2 1-hr NAAQS.
(c) Redesignation to attainment. As of February 28, 2022, the Jefferson County 2010 SO 2 nonattainment area is redesignated to attainment of the 2010 SO 2 1-hour National Ambient Air Quality Standard (NAAQS) in accordance with the requirements of Clean Air Act (CAA) section 107(d)(3) and EPA has approved its maintenance plan and supplemental modeling demonstration analyses as meeting the requirements of CAA section 175A.
(d) Redesignation to attainment. As of March 2, 2022, the Jackson County 2010 SO 2 nonattainment area is redesignated to attainment of the 2010 SO 2 1-hour National Ambient Air Quality Standard (NAAQS) in accordance with the requirements of Clean Air Act (CAA) section 107(d)(3) and EPA has approved its maintenance plan and maintenance plan supplement as meeting the requirements of CAA section 175A.
§ 52.1370   Identification of plan.
(a) Purpose and scope. This section sets forth the applicable State Implementation Plan for Montana under section 110 of the Clean Air Act, 42 U.S.C. 7410 and 40 CFR part 51 to meet national ambient air quality standards or other requirements under the Clean Air Act.
(b) Incorporation by reference. (1) Material listed in paragraphs (c), (d), and (e) of this section with an EPA approval date prior to March 1, 2015, was approved for incorporation by reference by the Director of the Federal Register in accordance with 5 U.S.C. 552(a) and 1 CFR part 51. Material is incorporated as submitted by the state to EPA, and notice of any change in the material will be published in the Federal Register. Entries for paragraphs (c), (d), and (e) of this section with EPA approval dates after March 1, 2015, will be incorporated by reference in the next update to the SIP compilation.
(2) EPA Region 8 certifies that the rules/regulations provided by EPA in the SIP compilation at the addresses in paragraph (b)(3) of this section are an exact duplicate of the officially promulgated state rules/regulations which have been approved as part of the State Implementation Plan as of March 1, 2015.
(3) Copies of the materials incorporated by reference may be inspected at the Environmental Protection Agency, Region 8, 1595 Wynkoop Street, Denver, Colorado 80202-1129; Air and Radiation Docket and Information Center, U.S. Environmental Protection Agency, West Building, 1301 Constitution Ave. NW., Washington, DC 20460; and, the National Archives and Records Administration (NARA). For information on the availability of materials from the docket in the EPA Headquarters Library, please call the Office of Air and Radiation (OAR) at (202) 566-1742. For information on the availability of this material at NARA, call (202) 741-6030, or go to http://www.archives.gov/federal-register/cfr/ibr-locations.html. Copies of the Montana regulations we have approved are also available at http://www.epa.gov/region8/air/sip.html.
(c) EPA-approved regulations.
(d) EPA-approved source-specific requirements.
(e) EPA-approved nonregulatory provisions .
§ 52.1371   Classification of regions.
The Montana Emergency Episode Avoidance Plan was revised with an August 2, 2004 submittal by the Governor. The August 2, 2004 Emergency Episode Avoidance Plan classified the Air Quality Control Regions (AQCR) as follows:
§ 52.1372   Approval status.
With the exceptions set forth in this subpart, the Administrator approves Montana's plans for the attainment and maintenance of the national standards under section 110 of the Clean Air Act. Furthermore, the Administrator finds the plans satisfy all requirements of Part D, Title I, of the Clean Air Act as amended in 1977, except as noted below.
§ 52.1373   Control strategy: Carbon monoxide.
(a) On July 8, 1997, the Governor of Montana submitted revisions to the SIP narrative for the Missoula carbon monoxide control plan.
(b) Revisions to the Montana State Implementation Plan, revised Carbon Monoxide Maintenance Plan for Billings, as submitted by the Governor's Designee on July 13, 2011, and the associated Alternative Monitoring Strategy for Billings, as submitted by the Governor's Designee on June 22, 2012.
(c) Revisions to the Montana State Implementation Plan, revised Carbon Monoxide Maintenance Plan for Great Falls, as submitted by the Governor's Designee on July 13, 2011, and the associated Alternative Monitoring Strategy for Great Falls, as submitted by the Governor's Designee on June 22, 2012.
(d) Revisions to the Montana State Implementation Plan, revised Carbon Monoxide Maintenance Plan for Missoula, as submitted by the Governor on September 19, 2016 (as approved by the EPA on February 1, 2018).
§ 52.1374   Control strategy: Particulate matter.
(a) On July 8, 1997, the Governor of Montana submitted minor revisions to the Columbia Falls, Butte and Missoula PM-10 SIPS.
(b) Determination —EPA has determined that the Whitefish PM 10 “moderate” nonattainment area attained the PM 10 national ambient air quality standard by December 31, 1999. This determination is based on air quality monitoring data from 1997, 1998, and 1999. EPA has determined that the Thompson Falls PM 10 “moderate” nonattainment area attained the PM 10 national ambient air quality standard by December 31, 2000. This determination is based on air quality monitoring data from 1998, 1999, and 2000.
(c) Determination of Attainment. EPA has determined, July 14, 2015, based on quality-assured air monitoring data for 2007-2009 and 2012-2014 ambient air quality data, that the Libby, MT fine particulate matter (PM 2.5 ) nonattainment area attained the 1997 annual PM 2.5 national ambient air quality standards (NAAQS). Therefore, EPA has met the requirement of CAA section 188(b)(2) to determine, based on the area's air quality as of the attainment date or as expeditiously as practicable, whether the area attained the 1997 annual PM 2.5 NAAQS. Additionally, this determination suspends the requirements for this area to submit an attainment demonstration, associated reasonably available control measures, a reasonable further progress plan, contingency measures, and other planning SIPs related to attainment of the standard for as long as this area continues to meet the 1997 annual PM 2.5 NAAQS. If EPA determines, after notice-and-comment rulemaking, that this area no longer meets the 1997 annual PM 2.5 NAAQS, the corresponding determination of attainment for that area shall be withdrawn.
(d) On August 3, 2016, the State of Montana submitted a maintenance plan for the Missoula PM 10 nonattainment area and requested that this area be redesignated to attainment for the PM 10 National Ambient Air Quality Standards. The redesignation request and maintenance plan satisfy all applicable requirements of the Clean Air Act.
(e) On July 23, 2019, the State of Montana submitted limited maintenance plans for the Columbia Falls, Kalispell and Libby PM 10 nonattainment areas and requested that these areas be redesignated to attainment for the PM 10 National Ambient Air Quality Standards. The redesignation request and limited maintenance plans satisfy all applicable requirements of the Clean Air Act.
(f) On March 23, 2020, the State of Montana submitted limited maintenance plans for the Butte PM 10 nonattainment areas and requested that this area be redesignated to attainment for the PM 10 National Ambient Air Quality Standards. The redesignation request and limited maintenance plans satisfy all applicable requirements of the Clean Air Act.
(g) On August 6, 2021, the State of Montana submitted limited maintenance plans for the Whitefish PM 10 nonattainment areas and requested that this area be redesignated to attainment for the PM 10 National Ambient Air Quality Standards. The redesignation request and limited maintenance plans satisfy all applicable requirements of the Clean Air Act.
(h) On November 4, 2021, the State of Montana submitted limited maintenance plans for the Thompson Falls PM 10 nonattainment areas and requested that this area be redesignated to attainment for the PM 10 National Ambient Air Quality Standards. The redesignation request and limited maintenance plans satisfy all applicable requirements of the Clean Air Act.
(i) On June 24, 2020, the State of Montana submitted limited maintenance plans for the Libby PM 2.5 nonattaiment areas and requested that this area be redesignated to attainment for the PM 2.5 National Ambient Air Quality Standards. The redesignation request and limited maintenance plans satisfy all applicable requirements of the Clean Air Act.
§ 52.1375   Control strategy: Lead.
(a) Determination—EPA has determined that the East Helena Lead nonattainment area has attained the lead national ambient air quality standards through calendar year 1999. This determination is based on air quality data currently in the AIRS database (as of the date of our determination, June 18, 2001).
(b) Redesignation to attainment—The EPA has determined that the East Helena lead (Pb) nonattainment area has met the criteria under CAA section 107(d)(3)(E) for redesignation from nonattainment to attainment for the 1978 Pb NAAQS. The EPA is therefore redesignating the East Helena 1978 Pb nonattainment area to attainment.
(c) Maintenance plan approval—The EPA is approving the maintenance plan for the East Helena nonattainment area for the 1978 Pb NAAQS submitted by the State of Montana on October 28, 2018.
§ 52.1376   Extensions.
On October 7, 1993, EPA granted the request by the State for the full three years allowed by section 172(b) of the CAA, as amended in 1990, for submittal of the SIP for the East Helena area to attain and maintain the sulfur dioxide secondary NAAQS. Therefore, the SIP for the area was due November 15, 1993. The SIP was not submitted by that date.
§ 52.1377   [Reserved]
§ 52.1378   General requirements.
(a) The requirements of § 51.116(c) of this chapter are not met since the legal authority to provide for public availability of emission data is inadequate.
(b) Regulation for public availability of emission data. (1) Any person who cannot obtain emission data from the Agency responsible for making emission data available to the public, as specified in the applicable plan, concerning emissions from any source subject to emission limitations which are part of the approved plan may request that the appropriate Regional Administrator obtain and make public such data. Within 30 days after receipt of any such written request, the Regional Administrator shall require the owner or operator of any such source to submit information within 30 days on the nature and amounts of emissions from such source and any other information as may be deemed necessary by the Regional Administrator to determine whether such source is in compliance with applicable emission limitations or other control measures that are part of the applicable plan.
(2) Commencing after the initial nonecessary by the Regional Administrator pursuant to paragraph (b)(1) of this section, the owner or operator of the source shall maintain records of the nature and amounts of emissions from such source and any other information as may be deemed necessary by the Regional Administrator to determine whether such source is in compliance with applicable emission limitations or other control measures that are part of the plan. The information recorded shall be summarized and reported to the Regional Administrator, on forms furnished by the Regional Administrator, and shall be submitted within 45 days after the end of the reporting period. Reporting periods are January 1 to June 30 and July 1 to December 31.
(3) Information recorded by the owner or operator and copies of this summarizing report submitted to the Regional Administrator shall be retained by the owner or operator for 2 years after the date on which the pertinent report is submitted.
(4) Emission data obtained from owners or operators of stationary sources will be correlated with applicable emission limitations and other control measures that are part of the applicable plan and will be available at the appropriate regional office and at other locations in the state designated by the Regional Administrator.
§ 52.1379   Legal authority.
(a) The requirements of § 51.230(f) of this chapter are not met, since section 69-3918 of the Montana Clean Air Act could, in some circumstances prohibit the disclosure of emission data to the public. Therefore, section 69-3918 is disapproved.
§§ 52.1380-52.1381   [Reserved]
§ 52.1382   Prevention of significant deterioration of air quality.
(a) The Montana plan, as submitted, is approved as meeting the requirements of Part C, Subpart 1 of the Clean Air Act, except that it does not apply to sources proposing to construct on Indian Reservations.
(b) Regulation for preventing significant deterioration of air quality. The provisions of § 52.21 except paragraph (a)(1) are hereby incorporated and made a part of the Montana State implementation plan and are applicable to proposed major stationary sources or major modifications to be located on Indian Reservations.
(c)(1) Except as set forth in this paragraph, all areas of Montana are designated Class II.
(2) The Northern Cheyene Indian Reservation is designated Class I.
(3) The Flathead Indian Reservation is designated Class I.
(4) The Fort Peck Indian Reservation is designated Class I.
§ 52.1384   Emission control regulations.
(a) Administrative Rules of Montana 17.8.309(5)(b) and 17.8.310(3)(e) of the State's rule regulating fuel burning, which were submitted by the Governor on April 14, 1999 and which allow terms of a construction permit to override a requirement that has been approved as part of the SIP, are disapproved. We cannot approve these provisions into the SIP, as it would allow the State to change a SIP requirement through the issuance of a permit. Pursuant to section 110 of the Act, to change a requirement of the SIP, the State must adopt a SIP revision and obtain our approval of the revision.
(b)(1) In 40 CFR 52.1370(c)(51), we incorporated by reference several documents that comprise the East Helena Lead SIP. Sections 52.1370(c)(51)(i)(B) and (C) indicate that certain provisions of the documents that were incorporated by reference were excluded. The excluded provisions of § 52.1370(c)(51)(i)(B) and (C) are disapproved. These provisions are disapproved because they do not entirely conform to the requirement of section 110(a)(2) of the Act that SIP limits must be enforceable, nor to the requirement of section 110(i) that the SIP can be modified only through the SIP revision process. The following phrases, words, or section in exhibit A of the stipulation between the Montana Department of Environmental Quality (MDEQ) and Asarco, adopted by order issued on June 26, 1996 by the Montana Board of Environmental Review (MBER), are disapproved:
(i) The words, “or an equivalent procedure” in the second and third sentences in section 2(A)(22) of exhibit A;
(ii) The words, “or an equivalent procedure” in the second and third sentences in section 2(A)(28) of exhibit A;
(iii) The words, “or an equivalent procedure” in the second sentence in section 5(G) of exhibit A;
(iv) The sentence, “Any revised documents are subject to review and approval by the Department as described in section 12,” from section 6(E) of exhibit A;
(v) The words, “or a method approved by the Department in accordance with the Montana Source Testing Protocol and Procedures Manual shall be used to measure the volumetric flow rate at each location identified,” in section 7(A)(2) of exhibit A;
(vi) The sentence, “Such a revised document shall be subject to review and approval by the Department as described in section 12,” in section 11(C) of exhibit A;
(vii) The sentences, “This revised Attachment shall be subject to the review and approval procedures outlined in Section 12(B). The Baghouse Maintenance Plan shall be effective only upon full approval of the plan, as revised. This approval shall be obtained from the Department by January 6, 1997. This deadline shall be extended to the extent that the Department has exceeded the time allowed in section 12(B) for its review and approval of the revised document,” in section 12(A)(7) of exhibit A; and
(viii) Section 12(B) of exhibit A.
(2) Paragraphs 15 and 16 of the stipulation by the MDEQ and Asarco adopted by order issued on June 26, 1996 by the MBER are disapproved. Paragraph 20 of the stipulation by the MDEQ and American Chemet adopted by order issued on August 4, 1995 by the MBER is disapproved.
(c) Administrative Rules of Montana 17.8.324(1)(c) and 2(d) (formerly ARM 16.8.1425(1)(c) and (2)(d)) of the State's rule regulating hydrocarbon emissions from petroleum products, which were submitted by the Governor on May 17, 1994 and later recodified with a submittal by the Governor on September 19, 1997, and which allow the discretion by the State to allow different equipment than that required by this rule, are disapproved. Such discretion cannot be allowed without requiring EPA review and approval of the alternative equipment to ensure that it is equivalent in efficiency to that equipment required in the approved SIP.
(d) In § 52.1370(c)(46), we approved portions of the Billings/Laurel Sulfur Dioxide SIP and incorporated by reference several documents. This paragraph identifies those portions of the Billings/Laurel SO2 SIP that have been disapproved.
(1) In § 52.1370(c)(46)(i)(A) through (G), certain provisions of the documents incorporated by reference were excluded. The following provisions that were excluded by § 52.1370(c)(46)(i)(A) through (G) are disapproved. We cannot approve these provisions because they do not conform to the requirements of the Clean Air Act:
(i) The following paragraph and portions of sections of the stipulation and exhibit A between the Montana Department of Environmental Quality and Cenex Harvest Cooperatives adopted by Board Order issued on June 12, 1998, by the Montana Board of Environmental Review:
(A) Paragraph 20 of the stipulation;
(B) The following phrase from section 3(B)(2) of exhibit A: “or in the flare”; and
(C) The following phrases in section 4(D) of exhibit A: “or in the flare” and “or the flare.”
(ii) Paragraph 20 of the stipulation between the Montana Department of Environmental Quality and Conoco, Inc., adopted by Board Order issued on June 12, 1998, by the Montana Board of Environmental Review.
(iii) The following paragraphs and portions of sections of the stipulation and exhibit A between the Montana Department of Environmental Quality and Exxon Company, USA, adopted by Board Order issued on June 12, 1998, by the Montana Board of Environmental Review:
(A) Paragraphs 1 and 22 of the stipulation;
(B) The following phrase of section 3(E)(4) of exhibit A: “or in the flare”; and
(C) The following phrases of section 4(E) of exhibit A: “or in the flare” and “or the flare.”
(iv) Paragraph 20 of the stipulation between the Montana Department of Environmental Quality and Montana Power Company, adopted by Board Order issued on June 12, 1998, by Montana Board of Environmental Review.
(v) The following paragraphs and sections of the stipulation and exhibit A between the Montana Department of Environmental Quality and Montana Sulphur & Chemical Company, adopted by Board Order issued on June 12, 1998, by the Montana Board of Environmental Review: paragraphs 1, 2 and 22 of the stipulation; sections 3(A)(1)(a) and (b), 3(A)(3), and 3(A)(4) of exhibit A.
(vi) Paragraph 20 of the stipulation between the Montana Department of Environmental Quality and Western Sugar Company, adopted by Board Order issued on June 12, 1998, by the Montana Board of Environmental Review.
(vii) Paragraph 20 of the stipulation between the Montana Department of Environmental Quality and Yellowstone Energy Limited Partnership, adopted by Board Order issued on June 12, 1998, by the Montana Board of Environmental Review.
(2) Section (3)(A)(2) of exhibit A of the stipulation between the Montana Department of Environmental Quality and Montana Sulphur & Chemical Company, adopted by Board Order issued on June 12, 1998, by the Montana Board of Environmental Review, which section 3(A)(2) we approved for the limited purpose of strengthening the SIP, is hereby disapproved. This limited disapproval does not prevent EPA, citizens, or the State from enforcing section 3(A)(2).
(e) In 40 CFR 52.1370(c)(52), we approved portions of the Billings/Laurel Sulfur Dioxide SIP for the limited purpose of strengthening the SIP. Those provisions that we limitedly approved are hereby limitedly disapproved. This limited disapproval does not prevent EPA, citizens, or the State from enforcing the provisions. This paragraph identifies those provisions of the Billings/Laurel SO 2 SIP identified in 40 CFR 52.1370(c)(52) that have been limitedly disapproved.
(1) Sections 3(B)(2) and 4(D) (excluding “or in the flare” and “or the flare” in both sections, which was previously disapproved in paragraphs (d)(1)(i)(B) and (C) above), 3(A)(1)(d) and 4(B) of Cenex Harvest State Cooperatives' exhibit A to the stipulation between the Montana Department of Environmental Quality and Cenex Harvest State Cooperatives, adopted June 12, 1998 by Board Order issued by the Montana Board of Environmental Review.
(2) Method #6A-1 of attachment #2 of Cenex Harvest State Cooperatives' exhibit A, as revised pursuant to the stipulation between the Montana Department of Environmental Quality and Cenex Harvest State Cooperatives, adopted by Board Order issued on March 17, 2000, by the Montana Board of Environmental Review.
(3) Sections 3(B)(2), 4(B), and 6(B)(3) of Exxon's exhibit A to the stipulation between the Montana Department of Environmental Quality and Exxon, adopted on June 12, 1998 by Board Order issued by the Montana Board of Environmental Review.
(4) Sections 2(A)(11)(d), 3(A)(1), 3(B)(1) and 4(C) of Exxon Mobil Corporation's exhibit A, as revised pursuant to the stipulation between the Montana Department of Environmental Quality and Exxon Mobil Corporation, adopted by Board Order issued on March 17, 2000, by the Montana Board of Environmental Review.
(f) Administrative Rules of Montana 17.8.335 of the State's rule entitled “Maintenance of Air Pollution Control Equipment for Existing Aluminum Plants,” submitted by the Governor on January 16, 2003, is disapproved. We cannot approve this rule into the SIP because it is inconsistent with the Act (e.g., sections 110(a) and 110(l)), prior rulemakings and our guidance.
§§ 52.1385-52.1386   [Reserved]
§ 52.1387   Visibility protection.
(a) The requirements of section 169A of the Clean Air Act are not met because the plan does not include approvable procedures for protection of visibility in mandatory Class I Federal areas.
(b) [Reserved]
(c) Montana's November 7, 2017 Progress Report meets the applicable regional haze requirements set forth in § 51.308(g) and (h).
§ 52.1388   Stack height regulations.
The State of Montana has committed to revise its stack height regulations should EPA complete rulemaking to respond to the decision in NRDC v. Thomas, 838 F. 2d 1224 (D.C. Cir. 1988). In a letter to Douglas M. Skie, EPA, dated May 6, 1988, Jeffrey T. Chaffee, Chief, Air Quality Bureau, stated:
* * * We are submitting this letter to allow EPA to continue to process our current SIP submittal with the understanding that if EPA's response to the NRDC remand modifies the July 8, 1985 regulations, EPA will notify the State of the rules that must be changed to comply with the EPA's modified requirements. The State of Montana agrees to make the appropriate changes.
§ 52.1389   [Reserved]
§ 52.1390   Missoula variance provision.
The Missoula City-County Air Pollution Control Program's Chapter X, Variances, which was adopted by the Montana Board of Health and Environmental Sciences on June 28, 1991 and submitted by the Governor of Montana to EPA in a letter dated August 20, 1991, is disapproved. This rule is inconsistent with section 110(i) of the Clean Air Act, which prohibits any State or EPA from granting a variance from any requirement of an applicable implementation plan with respect to a stationary source.
§ 52.1391   Emission inventories.
(a) The Governor of the State of Montana submitted the 1990 carbon monoxide base year emission inventories for Missoula and Billings on July 18, 1995, as a revision to the State Implementation Plan (SIP). The Governor submitted the 1990 carbon monoxide base year emission inventory for Great Falls on April 23, 1997, as a revision to the SIP. The inventories address emissions from point, area, on-road mobile, and non-road sources. These 1990 base year carbon monoxide inventories satisfy the nonattainment area requirements of the Clean Air Act of section 187(a)(1) for Missoula and section 172(c)(3) for Billings and Great Falls.
(b) As part of the Thompson Falls Air Pollution Control Plan (approved at § 52.1370(c)(60)), the Governor of Montana submitted a PM-10 emission inventory for the Thompson Falls area as a SIP revision. The PM-10 emission inventory covers the time period of July 1, 1990 through June 30, 1991.
§ 52.1392   Federal Implementation Plan for the Billings/Laurel Area.
(a) Applicability. This section applies to the owner(s) or operator(s), including any new owner(s) or operator(s) in the event of a change in ownership or operation, of the following facilities in the Billings/Laurel, Montana area: CHS Inc. Petroleum Refinery, Laurel Refinery, 803 Highway 212 South, Laurel, MT; ConocoPhillips Petroleum Refinery, Billings Refinery, 401 South 23rd St., Billings, MT; ExxonMobil Petroleum Refinery, 700 Exxon Road, Billings, MT; and Montana Sulphur & Chemical Company, 627 Exxon Road, Billings, MT.
(b) Scope. The facilities listed in paragraph (a) of this section are also subject to the Billings/Laurel SO 2 SIP, as approved at 40 CFR 52.1370(c)(46) and (52). In cases where the provisions of this FIP address emissions activities differently or establish a different requirement than the provisions of the approved SIP, the provisions of this FIP take precedence.
(c) Definitions. For the purpose of this section, we are defining certain words or initials as described in this paragraph. Terms not defined below that are defined in the Clean Air Act or regulations implementing the Clean Air Act, shall have the meaning set forth in the Clean Air Act or such regulations.
(1) Aliquot means a fractional part of a sample that is an exact divisor of the whole sample.
(2) Annual Emissions means the amount of SO 2 emitted in a calendar year, expressed in pounds per year rounded to the nearest pound, where:
(3) Calendar Day means a 24-hour period starting at 12 midnight and ending at 12 midnight, 24 hours later.
(4) Clock Hour means a twenty-fourth ( 1/24 ) of a calendar day; specifically any of the standard 60-minute periods in a day that are identified and separated on a clock by the whole numbers one (1) through 12.
(5) Continuous Emission Monitoring System or CEMS means all continuous concentration and volumetric flow rate monitors, associated data acquisition equipment, and all other equipment necessary to meet the requirements of this section for continuous monitoring.
(6) Daily Emissions means the amount of SO 2 emitted in a calendar day, expressed in pounds per day rounded to the nearest tenth ( 1/10 ) of a pound, where:
(7) EPA means the United States Environmental Protection Agency.
(8) Exhibit means for a given facility named in paragraph (a) of this section, exhibit A to the stipulation of the Montana Department of Environmental Quality and that facility, adopted by the Montana Board of Environmental Review on either June 12, 1998, or March 17, 2000.
(9) 1998 Exhibit means for a given facility named in paragraph (a) of this section, the exhibit adopted by the Montana Board of Environmental Review on June 12, 1998.
(10) 2000 Exhibit means for a given facility named in paragraph (a) of this section, the exhibit adopted by the Montana Board of Environmental Review on March 17, 2000.
(11) Flare means a combustion device that uses an open flame to burn combustible gases with combustion air provided by uncontrolled ambient air around the flame. This term includes both ground and elevated flares.
(12) The initials Hg mean mercury.
(13) Hourly means or refers to each clock hour in a calendar day.
(14) Hourly Average means an arithmetic average of all valid and complete 15-minute data blocks in a clock hour. Four (4) valid and complete 15-minute data blocks are required to determine an hourly average for each CEMS per clock hour.
(15) Hourly Emissions means the pounds per clock hour of SO 2 emissions from a source (including, but not limited to, a flare, stack, fuel oil system, sour water system, or fuel gas system) determined using hourly averages and rounded to the nearest tenth ( 1/10 ) of a pound.
(16) The initials H 2 S mean hydrogen sulfide.
(17) Integrated sampling means an automated method of obtaining a sample from the gas stream to the flare that produces a composite sample of individual aliquots taken over time.
(18) The initials MBER mean the Montana Board of Environmental Review.
(19) The initials MDEQ mean the Montana Department of Environmental Quality.
(20) The initials mm mean millimeters.
(21) The initials MSCC mean the Montana Sulphur & Chemical Company.
(22) Pilot gas means the gas used to maintain the presence of a flame for ignition of gases routed to a flare.
(23) Purge gas means a continuous gas stream introduced into a flare header, flare stack, and/or flare tip for the purpose of maintaining a positive flow that prevents the formation of an explosive mixture due to ambient air ingress.
(24) The initials ppm mean parts per million.
(25) The initials SCFH mean standard cubic feet per hour.
(26) The initials SCFM mean standard cubic feet per minute.
(27) Standard Conditions means (a) 20 °C (293.2 °K, 527.7 °R, or 68.0 °F) and one (1) atmosphere pressure (29.92 inches Hg or 760 mm Hg) for stack and flare gas emission calculations, and (b) 15.6 °C (288.7 °K, 520.0 °R, or 60.3 °F) and one (1) atmosphere pressure (29.92 inches Hg or 760 mm Hg) for refinery fuel gas emission calculations.
(28) The initials SO 2 mean sulfur dioxide.
(29) The initials SWS mean sour water stripper.
(30) The term 3-hour emissions means the amount of SO 2 emitted in each of the eight (8) non-overlapping 3-hour periods in a calendar day, expressed in pounds and rounded to the nearest tenth ( 1/10 ) of a pound, where:
(31) The term 3-hour period means any of the eight (8) non-overlapping 3-hour periods in a calendar day: Midnight to 3 a.m., 3 a.m. to 6 a.m., 6 a.m. to 9 a.m., 9 a.m. to noon, noon to 3 p.m., 3 p.m. to 6 p.m., 6 p.m. to 9 p.m., 9 p.m. to midnight.
(32) Turnaround means a planned activity involving shutdown and startup of one or several process units for the purpose of performing periodic maintenance, repair, replacement of equipment, or installation of new equipment.
(33) Valid means data that are obtained from a monitor or meter serving as a component of a CEMS which meets the applicable specifications, operating requirements, and quality assurance and control requirements of section 6 of ConocoPhillips', CHS Inc.'s, ExxonMobil's, and MSCC's 1998 exhibits, respectively, and this section.
(d) CHS Inc. emission limits and compliance determining methods— (1) Introduction. The provisions for CHS Inc. cover the following units:
(i) The flare.
(ii) Combustion sources, which consist of those sources identified in the combustion sources emission limit in section 3(A)(1)(d) of CHS Inc.'s 1998 exhibit.
(2) Flare requirements— (i) Emission limit. The total emissions of SO 2 from the flare shall not exceed 150.0 pounds per 3-hour period.
(ii) Compliance determining method. Compliance with the emission limit in paragraph (d)(2)(i) of this section shall be determined in accordance with paragraph (h) of this section.
(3) Combustion sources— (i) Restrictions. Sour water stripper overheads (ammonia (NH 3 ) and H 2 S gases removed from the sour water in the sour water stripper) shall not be burned in the main crude heater. At all times, CHS Inc. shall keep a chain and lock on the valve that supplies sour water stripper overheads from the old sour water stripper to the main crude heater and shall keep such valve closed.
(ii) Compliance determining method. CHS Inc. shall log and report any noncompliance with the requirements of paragraph (d)(3)(i) of this section.
(4) Data reporting requirements. (i) CHS Inc. shall submit quarterly reports beginning with the first calendar quarter following May 21, 2008. The quarterly reports shall be submitted within 30 days of the end of each calendar quarter. The quarterly reports shall be submitted to EPA at the following address: Air Program Contact, EPA Montana Operations Office, Federal Building, 10 West 15th Street, Suite 3200, Helena, MT 59626.
(ii) The electronic report shall be on magnetic or optical media, and such submittal shall follow the reporting format of electronic data being submitted to the MDEQ. EPA may modify the reporting format delineated in this section, and, thereafter, CHS Inc. shall follow the revised format. In addition to submitting the electronic quarterly reports to EPA, CHS Inc. shall also record, organize, and archive for at least five (5) years the same data, and upon request by EPA, CHS Inc. shall provide EPA with any data archived in accordance with this provision. The electronic report shall contain the following:
(A) Hourly average total sulfur concentrations as H 2 S or SO 2 in ppm in the gas stream to the flare;
(B) Hourly average H 2 S concentrations of the flare pilot and purge gases in ppm;
(C) Hourly average volumetric flow rates in SCFH of the gas stream to the flare;
(D) Hourly average volumetric flow rates in SCFH of the flare pilot and purge gases;
(E) Hourly average temperature (in °F) and pressure (in mm or inches of Hg) of the gas stream to the flare;
(F) Hourly emissions from the flare in pounds per clock hour; and
(G) Daily calibration data for all flare, pilot gas, and purge gas CEMS.
(iii) The quarterly written report shall contain the following information:
(A) The 3-hour emissions in pounds per 3-hour period from each flare;
(B) Periods in which only natural gas or an inert gas was used as flare pilot gas or purge gas or both;
(C) The results of all quarterly Cylinder Gas Audits (CGA), Relative Accuracy Audits (RAA), and annual Relative Accuracy Test Audits (RATA) for all total sulfur analyzer(s) and H 2 S analyzer(s), and the results of all annual calibrations and verifications for the volumetric flow, temperature, and pressure monitors;
(D) For all periods of flare volumetric flow rate monitoring system or total sulfur analyzer system downtime, flare pilot gas or purge gas volumetric flow or H 2 S analyzer system downtime, or failure to obtain or analyze a grab or integrated sample, the written report shall identify:
( 1 ) Dates and times of downtime or failure;
( 2 ) Reasons for downtime or failure;
( 3 ) Corrective actions taken to mitigate downtime or failure; and
( 4 ) The other methods, approved by EPA in the flare monitoring plan required by paragraph (h)(5) of this section, used to determine flare emissions;
(E) For all periods that the range of the flare or any pilot or purge gas volumetric flow rate monitor(s), any flare total sulfur analyzer(s), or any pilot or purge gas H 2 S analyzer(s) is exceeded, the written report shall identify:
( 1 ) Date and time when the range of the volumetric flow monitor(s), total sulfur analyzer(s), or H 2 S analyzer(s) was exceeded; and
( 2 ) The other methods, approved by EPA in the flare monitoring plan required by paragraph (h)(5) of this section, used to determine flare emissions;
(F) For all periods that the flare volumetric flow monitor or monitors are recording flow, yet any Flare Water Seal Monitoring Device indicates there is no flow, the written report shall identify:
( 1 ) Date, time, and duration when the flare volumetric flow monitor(s) recorded flow, yet any Flare Water Seal Monitoring Device indicated there was no flow;
(G) For each 3-hour period in which the flare emission limit is exceeded, the written report shall identify:
( 1 ) The date, start time, and end time of the excess emissions;
( 2 ) Total hours of operation with excess emissions, the hourly emissions, and the 3-hour emissions;
( 3 ) All information regarding reasons for operating with excess emissions; and
( 4 ) Corrective actions taken to mitigate excess emissions;
(H) The date and time of any noncompliance with the requirements of paragraph (d)(3)(i) of this section; and
(I) When no excess emissions have occurred or the continuous monitoring system(s) or manual system(s) have not been inoperative, repaired, or adjusted, such information shall be stated in the report.
(e) ConocoPhillips emission limits and compliance determining methods— (1) Introduction. The provisions for ConocoPhillips cover the following units:
(i) The main flare, which consists of two flares—the north flare and the south flare—that are operated on alternating schedules. These flares are referred to herein as the north main flare and south main flare, or generically as the main flare.
(ii) The Jupiter Sulfur SRU flare, which is the flare at Jupiter Sulfur, ConocoPhillips' sulfur recovery unit.
(2) Flare requirements— (i) Emission limits. (A) Combined emissions of SO 2 from the main flare (which can be emitted from either the north or south main flare, but not both at the same time) shall not exceed 150.0 pounds per 3-hour period.
(B) Emissions of SO 2 from the Jupiter Sulfur SRU flare and the Jupiter Sulfur SRU/ATS stack (also referred to as the Jupiter Sulfur SRU stack) shall not exceed 75.0 pounds per 3-hour period, 600.0 pounds per calendar day, and 219,000 pounds per calendar year.
(ii) Compliance determining method. (A) Compliance with the emission limit in paragraph (e)(2)(i)(A) of this section shall be determined in accordance with paragraph (h) of this section. In the event that a single monitoring location cannot be used for both the north and south main flare, ConocoPhillips shall monitor the flow and measure the total sulfur concentration at more than one location in order to determine compliance with the main flare emission limit. ConocoPhillips shall log and report any instances when emissions are vented from the north main flare and south main flare simultaneously.
(B) Compliance with the emission limits and requirements in paragraph (e)(2)(i)(B) of this section shall be determined by summing the emissions from the Jupiter Sulfur SRU flare and SRU/ATS stack. Emissions from the Jupiter Sulfur SRU flare shall be determined in accordance with paragraph (h) of this section and the emissions from the Jupiter Sulfur SRU/ATS stack shall be determined pursuant to ConocoPhillips' 1998 exhibit (see section 4(A) of the exhibit).
(3) Data reporting requirements. (i) ConocoPhillips shall submit quarterly reports on a calendar year basis, beginning with the first calendar quarter following May 21, 2008. The quarterly reports shall be submitted within 30 days of the end of each calendar quarter. The quarterly reports shall be submitted to EPA at the following address: Air Program Contact, EPA Montana Operations Office, Federal Building, 10 West 15th Street, Suite 3200, Helena, MT 59626.
(ii) The electronic report shall be on magnetic or optical media, and such submittal shall follow the reporting format of electronic data being submitted to the MDEQ. EPA may modify the reporting format delineated in this section, and, thereafter, ConocoPhillips shall follow the revised format. In addition to submitting the electronic quarterly reports to EPA, ConocoPhillips shall also record, organize, and archive for at least five (5) years the same data, and upon request by EPA, ConocoPhillips shall provide EPA with any data archived in accordance with this provision. The electronic report shall contain the following:
(A) Hourly average total sulfur concentrations as H 2 S or SO 2 in ppm in the gas stream to the ConocoPhillips main flare and Jupiter Sulfur SRU flare;
(B) Hourly average H 2 S concentrations of the ConocoPhillips main flare and Jupiter Sulfur SRU flare pilot and purge gases in ppm;
(C) Hourly average volumetric flow rates in SCFH of the gas streams to the ConocoPhillips main flare and Jupiter Sulfur SRU flare;
(D) Hourly average volumetric flow rates in SCFH of the ConocoPhillips main flare and Jupiter Sulfur SRU flare pilot and purge gases;
(E) Hourly average temperature (in °F) and pressure (in mm or inches of Hg) of the gas streams to the ConocoPhillips main flare and Jupiter Sulfur SRU flare;
(F) Hourly emissions in pounds per clock hour from the ConocoPhillips main flare and Jupiter Sulfur SRU flare; and
(G) Daily calibration data for all flare, pilot gas, and purge gas CEMS.
(iii) The quarterly written report shall contain the following information:
(A) The 3-hour emissions in pounds per 3-hour period from the ConocoPhillips main flare and the sum of the combined 3-hour emissions from the Jupiter Sulfur SRU/ATS stack and Jupiter Sulfur SRU flare in pounds per 3-hour period;
(B) Periods in which only natural gas or an inert gas was used as flare pilot gas or purge gas or both;
(C) The results of all quarterly Cylinder Gas Audits (CGA), Relative Accuracy Audits (RAA), and annual Relative Accuracy Test Audits (RATA) for all total sulfur analyzer(s) and H 2 S analyzer(s), and the results of all annual calibrations and verifications for the volumetric flow, temperature, and pressure monitors;
(D) For all periods of flare volumetric flow rate monitoring system or total sulfur analyzer system downtime, flare pilot gas or purge gas volumetric flow or H 2 S analyzer system downtime, or failure to obtain or analyze a grab or integrated sample, the written report shall identify:
( 1 ) Dates and times of downtime or failure;
( 2 ) Reasons for downtime or failure;
( 3 ) Corrective actions taken to mitigate downtime or failure; and
( 4 ) The other methods, approved by EPA in the flare monitoring plan required by paragraph (h)(5) of this section, used to determine flare emissions;
(E) For all periods that the range of the flare or any pilot or purge gas volumetric flow rate monitor(s), any flare total sulfur analyzer(s), or any pilot or purge gas H 2 S analyzer(s) is exceeded, the written report shall identify:
( 1 ) Date and time when the range of the volumetric flow monitor(s), total sulfur analyzer(s), or H 2 S analyzer(s) was exceeded, and
( 2 ) The other methods, approved by EPA in the flare monitoring plan required by paragraph (h)(5) of this section, used to determine flare emissions;
(F) For all periods that the flare volumetric flow monitor or monitors are recording flow, yet any Flare Water Seal Monitoring Device indicates there is no flow, the written report shall identify:
( 1 ) Date, time, and duration when the flare volumetric flow monitor(s) recorded flow, yet any Flare Water Seal Monitoring Device indicated there was no flow;
(G) Identification of dates, times, and duration of any instances when emissions were vented from the north and south main flares simultaneously;
(H) For each 3-hour period in which a flare emission limit is exceeded, the written report shall identify:
( 1 ) The date, start time, and end time of the excess emissions;
( 2 ) Total hours of operation with excess emissions, the hourly emissions, and the 3-hour emissions;
( 3 ) All information regarding reasons for operating with excess emissions; and
( 4 ) Corrective actions taken to mitigate excess emissions; and
(I) When no excess emissions have occurred or the continuous monitoring system(s) or manual system(s) have not been inoperative, repaired, or adjusted, such information shall be stated in the report.
(f) ExxonMobil emission limits and compliance determining methods— (1) Introduction. The provisions for ExxonMobil cover the following units:
(i) The Primary process flare and the Turnaround flare. The Primary process flare is the flare normally used by ExxonMobil. The Turnaround flare is the flare ExxonMobil uses for about 30 to 40 days every 5 to 6 years when the facility's major SO 2 source, the fluid catalytic cracking unit, is not normally operating.
(ii) The following refinery fuel gas combustion units: The FCC CO Boiler, F-2 crude/vacuum heater, F-3 unit, F-3X unit, F-5 unit, F-700 unit, F-201 unit, F-202 unit, F-402 unit, F-551 unit, F-651 unit, standby boiler house (B-8 boiler), and Coker CO Boiler (only when the Yellowstone Energy Limited Partnership (YELP) facility is receiving ExxonMobil Coker unit flue gas or whenever the ExxonMobil Coker is not operating).
(iii) Coker CO Boiler stack.
(2) Flare requirements— (i) Emission limit. The total combined emissions of SO 2 from the Primary process and Turnaround refinery flares shall not exceed 150.0 pounds per 3-hour period.
(ii) Compliance determining method. Compliance with the emission limit in paragraph (f)(2)(i) of this section shall be determined in accordance with paragraph (h) of this section. If volumetric flow monitoring device(s) installed and concentration monitoring methods used to measure the gas stream to the Primary Process flare cannot measure the gas stream to the Turnaround flare, ExxonMobil may apply to EPA for alternative measures to determine the volumetric flow rate and total sulfur concentration of the gas stream to the Turnaround flare. Before EPA will approve such alternative measures, ExxonMobil must agree that the Turnaround flare will be used only during refinery turnarounds of limited duration and frequency—no more than 60 days once every five (5) years—which restriction shall be considered an enforceable part of this FIP. Such alternative measures may consist of reliable flow estimation parameters to estimate volumetric flow rate and manual sampling of the gas stream to the flare to determine total sulfur concentrations, or such other measures that EPA finds will provide accurate estimations of SO 2 emissions from the Turnaround flare.
(3) Refinery fuel gas combustion requirements— (i) Emission limits. The applicable emission limits are contained in section 3(A)(1) of ExxonMobil's 2000 exhibit and section 3(B)(2) of ExxonMobil's 1998 exhibit.
(ii) Compliance determining method. For the limits referenced in paragraph (f)(3)(i) of this section, the compliance determining methods specified in section 4(B) of ExxonMobil's 1998 exhibit shall be followed except when the H 2 S concentration in the refinery fuel gas stream exceeds 1200 ppmv as measured by the H 2 S CEMS required by section 6(B)(3) of ExxonMobil's 1998 exhibit (the H 2 S CEMS.) When such value is exceeded, the following compliance monitoring method shall be employed:
(A) ExxonMobil shall measure the H 2 S concentration in the refinery fuel gas according to the procedures in paragraph (f)(3)(ii)(B) of this section and calculate the emissions according to the equations in paragraph (f)(3)(ii)(C) of this section.
(B) Within four (4) hours after the H 2 S CEMS measures an H 2 S concentration in the refinery fuel gas stream greater than 1200 ppmv, ExxonMobil shall initiate sampling of the refinery fuel gas stream at the fuel header on a once-per-hour frequency using length-of-stain detector tubes pursuant to ASTM Method D4810-06, “Standard Test Method for Hydrogen Sulfide in Natural Gas Using Length-of-Stain Detector Tubes” (incorporated by reference, see paragraph (j) of this section) with the appropriate sample tube range. If the results exceed the tube's range, another tube of a higher range must be used until results are in the tube's range. ExxonMobil shall continue to use the length-of-stain detector tube method at this frequency until the H 2 S CEMS measures an H 2 S concentration in the refinery fuel gas stream equal to or less than 1200 ppmv continuously over a 3-hour period.
(C) When the length-of-stain detector tube method is required, SO 2 emissions from refinery fuel gas combustion shall be calculated as follows: the Hourly emissions shall be calculated using equation 1, 3-hour emissions shall be calculated using equation 2, and the Daily emissions shall be calculated using equation 3.
(4) Coker CO Boiler stack requirements— (i) Emission limits. When ExxonMobil's Coker unit is operating and Coker unit flue gases are burned in the Coker CO Boiler, the applicable emission limits are contained in section 3(B)(1) of ExxonMobil's 2000 exhibit.
(ii) Compliance determining method. (A) Compliance with the emission limits referenced in paragraph (f)(4)(i) of this section shall be determined by measuring the SO 2 concentration and flow rate in the Coker CO Boiler stack according to the procedures in paragraphs (f)(4)(ii)(B) and (C) of this section and calculating emissions according to the equations in paragraph (f)(4)(ii)(D) of this section.
(B) Beginning on May 21, 2008, ExxonMobil shall operate and maintain a CEMS to measure sulfur dioxide concentrations in the Coker CO Boiler stack. Whenever ExxonMobil's Coker unit is operating and Coker unit flue gases are exhausted through the Coker CO Boiler stack, the CEMS shall be operational and shall achieve a temporal sampling resolution of at least one (1) concentration measurement per minute, meet the requirements expressed in the definition of “hourly average” in paragraph (c)(14) of this section, and meet the CEMS Performance Specifications contained in section 6(C) of ExxonMobil's 1998 exhibit, except that ExxonMobil shall perform a Cylinder Gas Audit (CGA) or Relative Accuracy Audit (RAA) which meets the requirements of 40 CFR part 60, Appendix F, within eight (8) hours of when the Coker unit flue gases begin exhausting through the Coker CO Boiler stack. ExxonMobil shall perform an annual Relative Accuracy Test Audit (RATA) on the CEMS and notify EPA in writing of each annual RATA a minimum of 25 working days prior to actual testing.
(C) Beginning on May 21, 2008, ExxonMobil shall operate and maintain a continuous stack flow rate monitor to measure the stack gas flow rates in the Coker CO Boiler stack. Whenever ExxonMobil's Coker unit is operating and Coker unit flue gases are exhausted through the Coker CO Boiler stack, this CEMS shall be operational and shall achieve a temporal sampling resolution of at least one (1) flow rate measurement per minute, meet the requirements expressed in the definition of “hourly average” in paragraph (c)(14) of this section, and meet the Stack Gas Flow Rate Monitor Performance Specifications of section 6(D) of ExxonMobil's 1998 exhibit, except that ExxonMobil shall perform an annual Relative Accuracy Test Audit (RATA) on the CEMS and notify EPA in writing of each annual RATA a minimum of 25 working days prior to actual testing.
(D) SO 2 emissions from the Coker CO Boiler stack shall be determined in accordance with the equations in sections 2(A)(1), (8), (11)(a), and (16) of ExxonMobil's 1998 exhibit.
(5) Data reporting requirements. (i) ExxonMobil shall submit quarterly reports beginning with the first calendar quarter following May 21, 2008. The quarterly reports shall be submitted within 30 days of the end of each calendar quarter. The quarterly reports shall be submitted to EPA at the following address: Air Program Contact, EPA Montana Operations Office, Federal Building, 10 West 15th Street, Suite 3200, Helena, MT 59626.
The quarterly report shall be certified for accuracy in writing by a responsible ExxonMobil official. The quarterly report shall consist of both a comprehensive electronic-magnetic report and a written hard copy data summary report.
(ii) The electronic report shall be on magnetic or optical media, and such submittal shall follow the reporting format of electronic data being submitted to the MDEQ. EPA may modify the reporting format delineated in this section, and, thereafter, ExxonMobil shall follow the revised format. In addition to submitting the electronic quarterly reports to EPA, ExxonMobil shall also record, organize, and archive for at least five (5) years the same data, and upon request by EPA, ExxonMobil shall provide EPA with any data archived in accordance with this provision. The electronic report shall contain the following:
(A) Hourly average total sulfur concentrations as H 2 S or SO 2 in ppm in the gas stream to the flare(s);
(B) Hourly average H 2 S concentrations of the flare pilot and purge gases in ppm;
(C) Hourly average SO 2 concentrations in ppm from the Coker CO Boiler stack;
(D) Hourly average volumetric flow rates in SCFH of the flare pilot and purge gases;
(E) Hourly average volumetric flow rates in SCFH in the gas stream to the flare(s) and in the Coker CO Boiler stack;
(F) Hourly average H 2 S concentrations in ppm from the refinery fuel gas system;
(G) Hourly average refinery fuel gas combustion units' actual fuel firing rate in SCFH;
(H) Hourly average temperature (in °F) and pressure (in mm or inches of Hg) of the gas stream to the flare(s);
(I) Hourly emissions in pounds per clock hour from the flare(s), Coker CO Boiler stack, and refinery fuel gas combustion system; and
(J) Daily calibration data for the CEMS described in paragraphs (f)(2)(ii), (f)(3)(ii) and (f)(4)(ii) of this section.
(iii) The quarterly written report shall contain the following information:
(A) The 3-hour emissions in pounds per 3-hour period from the flare(s), Coker CO Boiler stack, and refinery fuel gas combustion system;
(B) Periods in which only natural gas or an inert gas was used as flare pilot gas or purge gas or both;
(C) Daily emissions in pounds per calendar day from the Coker CO Boiler stack and refinery fuel gas combustion system;
(D) The results of all quarterly or other Cylinder Gas Audits (CGA), Relative Accuracy Audits (RAA), and annual Relative Accuracy Test Audits (RATA) for the CEMS described in paragraphs (f)(2)(ii) (flare total sulfur analyzer(s); pilot gas or purge gas H 2 S analyzer(s)), (f)(3)(ii), and (f)(4)(ii) of this section, and the results of all annual calibrations and verifications for the volumetric flow, temperature, and pressure monitors;
(E) For all periods of flare volumetric flow rate monitoring system or total sulfur analyzer system downtime, Coker CO Boiler stack CEMS downtime, refinery fuel gas combustion system CEMS downtime, flare pilot gas or purge gas volumetric flow or H 2 S analyzer system downtime, or failure to obtain or analyze a grab or integrated sample, the written report shall identify:
( 1 ) Dates and times of downtime or failure;
( 2 ) Reasons for downtime or failure;
( 3 ) Corrective actions taken to mitigate downtime or failure; and
( 4 ) The other methods, approved by EPA in the flare monitoring plan required by paragraph (h)(5) of this section, used to determine flare emissions;
(F) For all periods that the range of the flare or any pilot or purge gas volumetric flow rate monitor(s), any flare total sulfur analyzer(s), or any pilot or purge gas H 2 S analyzer(s) is exceeded, the written report shall identify:
( 1 ) Date and time when the range of the volumetric flow monitor(s), total sulfur analyzer(s), or H 2 S analyzer(s) was exceeded, and
( 2 ) The other methods, approved by EPA in the flare monitoring plan required by paragraph (h)(5) of this section, used to determine flare emissions;
(G) For all periods that the range of the refinery fuel gas CEMS is exceeded, the written report shall identify:
( 1 ) Date, time, and duration when the range of the refinery fuel gas CEMS was exceeded;
(H) For all periods that the flare volumetric flow monitor or monitors are recording flow, yet any Flare Water Seal Monitoring Device indicates there is no flow, the written report shall identify:
( 1 ) Date, time, and duration when the flare volumetric flow monitor(s) recorded flow, yet any Flare Water Seal Monitoring Device indicated there was no flow;
(I) For each 3-hour period and calendar day in which the flare emission limits, the Coker CO Boiler stack emission limits, or the fuel gas combustion system emission limits are exceeded, the written report shall identify:
( 1 ) The date, start time, and end time of the excess emissions;
( 2 ) Total hours of operation with excess emissions, the hourly emissions, the 3-hour emissions, and the daily emissions;
( 3 ) All information regarding reasons for operating with excess emissions; and
( 4 ) Corrective actions taken to mitigate excess emissions; and
(J) When no excess emissions have occurred or the continuous monitoring system(s) or manual system(s) have not been inoperative, repaired, or adjusted, such information shall be stated in the report.
(g) Montana Sulphur & Chemical Company (MSCC) emission limits and compliance determining methods —(1) Introduction. The provisions for MSCC cover the following units:
(i) The flares, which consist of the 80-foot west flare, 125-foot east flare, and 100-meter flare.
(ii) The SRU 100-meter stack.
(iii) The auxiliary vent stacks and the units that can exhaust through the auxiliary vent stacks, which consist of the Railroad Boiler, the H-1 Unit, the H1-A unit, the H1-1 unit and the H1-2 unit.
(iv) The SRU 30-meter stack and the units that can exhaust through the SRU 30-meter stack. The units that can exhaust through the SRU 30-meter stack are identified in section 3(A)(2)(d) and (e) of MSCC's 1998 exhibit.
(2) Flare requirements— (i) Emission limit. Total combined emissions of SO 2 from the 80-foot west flare, 125-foot east flare, and 100-meter flare shall not exceed 150.0 pounds per 3-hour period.
(ii) Compliance determining method. Compliance with the emission limit in paragraph (g)(2)(i) of this section shall be determined in accordance with paragraph (h) of this section. In the event MSCC cannot monitor all three flares from a single location, MSCC shall establish multiple monitoring locations.
(3) SRU 100-meter stack requirements— (i) Emission limits. Emissions of SO 2 from the SRU 100-meter stack shall not exceed:
(A) 2,981.7 pounds per 3-hour period;
(B) 23,853.6 pounds per calendar day; and
(C) 9,088,000 pounds per calendar year.
(ii) Compliance determining method. (A) Compliance with the emission limits contained in paragraph (g)(3)(i) of this section shall be determined by the CEMS and emission testing methods required by sections 6(B)(1) and (2) and section 5, respectively, of MSCC's 1998 exhibit.
(B) MSCC shall notify EPA in writing of each annual source test a minimum of 25 working days prior to actual testing.
(C) The CEMS referenced in paragraph (g)(3)(ii)(A) of this section shall achieve a temporal sampling resolution of at least one (1) concentration and flow rate measurement per minute, meet the requirements expressed in the definition of “hourly average” in paragraph (c)(14) of this section, and meet the “CEM Performance Specifications” in sections 6(C) and (D) of MSCC's 1998 exhibit, except that MSCC shall also notify EPA in writing of each annual Relative Accuracy Test Audit at least 25 working days prior to actual testing.
(4) Auxiliary vent stacks— (i) Emission limits. (A) Total combined emissions of SO 2 from the auxiliary vent stacks shall not exceed 12.0 pounds per 3-hour period;
(B) Total combined emissions of SO 2 from the auxiliary vent stacks shall not exceed 96.0 pounds per calendar day;
(C) Total combined emissions of SO 2 from the auxiliary vent stacks shall not exceed 35,040 pounds per calendar year; and
(D) The H 2 S concentration in the fuel burned in the Railroad Boiler, the H-1 Unit, the H1-A unit, the H1-1 unit, and the H1-2 unit, while any of these units is exhausting to the auxiliary vent stacks, shall not exceed 160 ppm per 3-hour period and 100 ppm per calendar day.
(ii) Compliance determining method. (A) Compliance with the emission limits in paragraph (g)(4)(i) of this section shall be determined by measuring the H 2 S concentration of the fuel burned in the Railroad Boiler, the H-1 Unit, the H1-A unit, the H1-1 unit, and the H1-2 unit (when fuel other than natural gas is burned in one or more of these units) according to the procedures in paragraph (g)(4)(ii)(C) of this section.
(B) Beginning June 20, 2008, MSCC shall maintain logs of:
( 1 ) The dates and time periods that emissions are exhausted through the auxiliary vent stacks,
( 2 ) The heaters and boilers that are exhausting to the auxiliary vent stacks during such time periods, and
( 3 ) The type of fuel burned in the heaters and boilers during such time periods.
(C) Beginning June 20, 2008, MSCC shall measure the H 2 S content of the fuel burned when fuel other than natural gas is burned in a heater or boiler that is exhausting to an auxiliary vent stack. MSCC shall begin measuring the H 2 S content of the fuel at the fuel header within one (1) hour from when a heater or boiler begins exhausting to an auxiliary vent stack and on a once-per-3-hour period frequency until no heater or boiler is exhausting to an auxiliary vent stack. To determine the H 2 S content of the fuel burned, MSCC shall use length-of-stain detector tubes pursuant to ASTM Method D4810-06, “Standard Test Method for Hydrogen Sulfide in Natural Gas Using Length-of-Stain Detector Tubes” (incorporated by reference, see paragraph (j) of this section) with the appropriate sample tube range. If the results exceed the tube's range, another tube of a higher range must be used until results are in the tube's range.
(5) SRU 30-meter stack— (i) Emission limits. (A) Emissions of SO 2 from the SRU 30-meter stack shall not exceed 12.0 pounds per 3-hour period;
(B) Emissions of SO 2 from the SRU 30-meter stack shall not exceed 96.0 pounds per calendar day;
(C) Emissions of SO 2 from the SRU 30-meter stack shall not exceed 35,040 pounds per calendar year; and
(D) The H 2 S concentration in the fuel burned in the heaters and boilers described in paragraph (g)(1)(iv) of this section, while any of these units is exhausting to the SRU 30-meter stack, shall not exceed 160 ppm per 3-hour period and 100 ppm per calendar day.
(ii) Compliance determining method. (A) Compliance with the emission limits in paragraph (g)(5)(i) of this section shall be determined by measuring the H 2 S concentration of the fuel burned in the heaters and boilers described in paragraph (g)(1)(iv) of this section (when fuel other than natural gas is burned in one or more of these heaters or boilers) according to the procedures in paragraph (g)(5)(ii)(C) of this section.
(B) Beginning June 20, 2008, MSCC shall maintain logs of:
( 1 ) The dates and time periods that emissions are exhausted through the SRU 30-meter stack,
( 2 ) The heaters and boilers that are exhausting to the SRU 30-meter stack during such time periods, and
( 3 ) The type of fuel burned in the heaters and boilers during such time periods.
(C) Beginning June 20, 2008, MSCC shall measure the H 2 S content of the fuel burned when fuel other than natural gas is burned in a heater or boiler that is exhausting to the SRU 30-meter stack. MSCC shall begin measuring the H 2 S content of the fuel at the fuel header within one (1) hour from when any heater or boiler begins exhausting to the SRU 30-meter stack and on a once-per-3-hour period frequency until no heater or boiler is exhausting to the SRU 30-meter stack. To determine the H 2 S content of the fuel burned, MSCC shall use length-of-stain detector tubes pursuant to ASTM Method D4810-06, “Standard Test Method for Hydrogen Sulfide in Natural Gas Using Length-of-Stain Detector Tubes” (incorporated by reference, see paragraph (j) of this section) with the appropriate sample tube range. If the results exceed the tube's range, another tube of a higher range must be used until results are in the tube's range.
(6) Data reporting requirements:
(i) MSCC shall submit quarterly reports beginning with the first calendar quarter following May 21, 2008. The quarterly reports shall be submitted within 30 days of the end of each calendar quarter. The quarterly reports shall be submitted to EPA at the following address: Air Program Contact, EPA Montana Operations Office, Federal Building, 10 West 15th Street, Suite 3200, Helena, MT 59626.
(ii) The electronic report shall be on magnetic or optical media, and such submittal shall follow the reporting format of electronic data being submitted to the MDEQ. EPA may modify the reporting format delineated in this section, and, thereafter, MSCC shall follow the revised format. In addition to submitting the electronic quarterly reports to EPA, MSCC shall also record, organize, and archive for at least five (5) years the same data, and upon request by EPA, MSCC shall provide EPA with any data archived in accordance with this provision. The electronic report shall contain the following:
(A) Hourly average total sulfur concentrations as H 2 S or SO 2 in ppm, in the gas stream to the flare(s);
(B) Hourly average H 2 S concentrations of the flare pilot and purge gases in ppm;
(C) Hourly average SO 2 concentrations in ppm from the SRU 100-meter stack;
(D) Hourly average volumetric flow rates in SCFH in the gas stream to the flare(s) and in the SRU 100-meter stack;
(E) Hourly average volumetric flow rates in SCFH of the flare pilot and purge gases;
(F) Hourly average temperature (in (F) and pressure (in mm or inches of Hg) in the gas stream to the flare(s);
(G) Hourly emissions in pounds per clock hour from the flare(s) and SRU 100-meter stack;
(H) Daily calibration data for all flare CEMS, all pilot gas and purge gas CEMS, and the SRU 100-meter stack CEMS;
(iii) The quarterly written report shall contain the following information:
(A) The 3-hour emissions in pounds per 3-hour period from the flare(s) and SRU 100-meter stack, and 3-hour H 2 S concentrations in the fuel burned in the heaters and boilers described in paragraphs (g)(1)(iii) and (iv) of this section while any of these units is exhausting to the SRU 30-meter stack or auxiliary vent stacks and burning fuel other than natural gas;
(B) Periods in which only natural gas or an inert gas was used as flare pilot gas or purge gas or both;
(C) Daily emissions in pounds per calendar day from the SRU 100-meter stack;
(D) Annual emissions of SO 2 in pounds per calendar year from the SRU 100-meter stack;
(E) The results of all quarterly Cylinder Gas Audits (CGA), Relative Accuracy Audits (RAA) and annual Relative Accuracy Test Audits (RATA) for all total sulfur analyzer(s), all H 2 S analyzer(s), and the SRU 100-meter stack CEMS, and the results of all annual calibrations and verifications for the volumetric flow, temperature, and pressure monitors;
(F) For all periods of flare volumetric flow rate monitoring system or total sulfur analyzer system downtime, SRU 100-meter CEMS downtime, flare pilot gas or purge gas volumetric flow or H 2 S analyzer system downtime, failure to obtain or analyze a grab or integrated sample, or failure to obtain an H 2 S concentration sample as required by paragraphs (g)(4)(ii)(C) and (g)(5)(ii)(C) of this section, the written report shall identify:
( 1 ) Dates and times of downtime or failure;
( 2 ) Reasons for downtime or failure;
( 3 ) Corrective actions taken to mitigate downtime or failure; and
( 4 ) The other methods, approved by EPA in the flare monitoring plan required by paragraph (h)(5) of this section, used to determine flare emissions;
(G) For all periods that the range of the flare or any pilot or purge gas volumetric flow rate monitor(s), any flare total sulfur analyzer(s), or any pilot or purge gas H 2 S analyzer(s), is exceeded, the written report shall identify:
( 1 ) Date and time when the range of the volumetric flow monitor(s), total sulfur analyzer(s), or H 2 S analyzer(s) was exceeded; and
( 2 ) The other methods, approved by EPA in the flare monitoring plan required by paragraph (h)(5) of this section, used to determine flare emissions;
(H) For all periods that the flare volumetric flow monitor or monitors are recording flow, yet any Flare Water Seal Monitoring Device indicates there is no flow, the written report shall identify:
( 1 ) Date, time, and duration when the flare volumetric flow monitor(s) recorded flow, yet any Flare Water Seal Monitoring Device indicated there was no flow;
(I) For each 3-hour period and calendar day in which the flare emission limit, the SRU 100-meter stack emission limits, the SRU 30-meter stack emission limits, or auxiliary vent stack emission limits are exceeded, the written report shall identify:
( 1 ) The date, start time, and end time of the excess emissions;
( 2 ) Total hours of operation with excess emissions, the hourly emissions, the 3-hour emissions, and the daily emissions;
( 3 ) All information regarding reasons for operating with excess emissions; and
( 4 ) Corrective actions taken to mitigate excess emissions;
(J) For instances in which emissions are exhausted through the auxiliary vent stacks or 30-meter stack, the quarterly written report shall identify:
( 1 ) The dates and time periods that emissions were exhausted through the auxiliary vent stacks or the 30-meter stack;
( 2 ) The heaters and boilers that were exhausting to the auxiliary vent stacks or 30-meter stack during such time periods; and
( 3 ) The type of fuel burned in the heaters and boilers during such time periods; and
(K) When no excess emissions have occurred or the continuous monitoring system(s) or manual system(s) have not been inoperative, repaired, or adjusted, such information shall be stated in the report.
(h) Flare compliance determining method. (1) Compliance with the emission limits in paragraphs (d)(2)(i), (e)(2)(i), (f)(2)(i) and (g)(2)(i) of this section shall be determined by measuring the total sulfur concentration and volumetric flow rate of the gas stream to the flare(s) (corrected to one (1) atmosphere pressure and 68 °F) and using the methods contained in the flare monitoring plan required by paragraph (h)(5) of this section. The volumetric flow rate of the gas stream to the flare(s) shall be determined in accordance with the requirements in paragraph (h)(2) of this section and the total sulfur concentration of the gas stream to the flare(s) shall be determined in accordance with paragraph (h)(3) of this section.
(2) Flare flow monitoring: (i) Within 365 days after receiving EPA approval of the flare monitoring plan required by paragraph (h)(5) of this section, each facility named in paragraph (a) of this section shall install and calibrate, and, thereafter, calibrate, maintain and operate, a continuous flow monitoring system capable of measuring the volumetric flow of the gas stream to the flare(s) in accordance with the specifications contained in paragraphs (h)(2)(iii) through (vi) of this section. The flow monitoring system shall require more than one flow monitoring device or flow measurements at more than one location if one monitor cannot measure the total volumetric flow to each flare.
(ii) Volumetric flow monitors meeting the proposed volumetric flow monitoring specifications below should be able to measure the majority of volumetric flow in the gas streams to the flare. However, in rare events (e.g., upset conditions) the flow to the flare may exceed the range of the monitor. In such cases, or when the volumetric flow monitor or monitors are not working, other methods approved by EPA in the flare monitoring plan required by paragraph (h)(5) of this section shall be used to determine the volumetric flow rate to the flare, which shall then be used to calculate SO 2 emissions. In quarterly reports, sources shall indicate when these other methods are used.
(iii) The flare gas stream volumetric flow rate shall be measured on an actual wet basis, converted to Standard Conditions, and reported in SCFH. The minimum detectable velocity of the flow monitoring device(s) shall be 0.1 feet per second (fps). The flow monitoring device(s) shall continuously measure the range of flow rates corresponding to velocities from 0.5 to 275 fps and have a manufacturer's specified accuracy of ±5% of the measured flow over the range of 1.0 to 275 fps and ±20% of the measured flow over the range of 0.1 to 1.0 fps. The volumetric flow monitor(s) shall feature automated daily calibrations at low and high ranges. The volumetric flow monitor(s) shall be calibrated annually according to manufacturer's specifications.
(iv) For correcting flow rate to standard conditions (defined as 68 °F and 760 mm, or 29.92 inches, of Hg), temperature and pressure shall be monitored continuously. Temperature and pressure shall be monitored in the same location as volumetric flow, and the temperature and pressure monitors shall be calibrated prior to installation according to manufacturer's specifications and, thereafter, annually to meet accuracy specifications as follows: The temperature monitor shall be calibrated to within ±2.0% at absolute temperature and the pressure monitor shall be calibrated to within ±5.0 mmHg;
(v) The flow monitoring device(s) shall be calibrated prior to installation to demonstrate accuracy of the measured flow to within 5.0% at flow rates equivalent to 30%, 60%, and 90% of monitor full scale.
(vi) Each volumetric flow device shall achieve a temporal sampling resolution of at least one (1) flow rate measurement per minute, meet the requirements expressed in the definition of “hourly average” in paragraph (c)(14) of this section, and be installed in a manner and at a location that will allow for accurate measurements of the total volume of the gas stream going to each flare. Each temperature and pressure monitoring device shall achieve a temporal sampling resolution of at least one (1) measurement per minute, meet the requirements expressed in the definition of “hourly average” in paragraph (c)(14) of this section, and be installed in a manner that will allow for accurate measurements.
(vii) In addition to the continuous flow monitors, facilities may use flare water seal monitoring devices to determine whether there is flow going to the flare. If used, owners or operators shall install, calibrate, operate, and maintain these devices according to manufacturer's specifications. The devices shall include a continuous monitoring system that:
(A) Monitors the status of the water seal to indicate when flow is going to the flare;
(B) Automatically records the time and duration when flow is going to the flare; and
(C) Verifies that the physical seal has been restored after flow has been sent to the flare.
If the water seal monitoring devices indicate that there is no flow going to the flare, yet the continuous flow monitor is indicating flow, the presumption will be that no flow is going to the flare.
(viii) Each facility named in paragraph (a) of this section, that does not certify that only natural gas or an inert gas is used for both the pilot gas and purge gas, shall determine the volumetric flow of each pilot gas and purge gas stream for which natural gas or inert gas is not used by one of the following methods:
(A) Measure the volumetric flow of the gas using continuous flow monitoring devices on an actual wet basis, converted to Standard Conditions, and reported in SCFH. Each flow monitoring device shall achieve a temporal sampling resolution of at least one (1) flow rate measurement per minute, meet the requirements expressed in the definition of “hourly average” in paragraph (c)(14) of this section, and be installed in a manner and at a location that will allow for accurate measurements of the total volume of the gas. Gas flow rate monitor accuracy determinations shall be required at least once every 48 months or more frequently at routine refinery turn-around. In cases when the flow monitoring device or devices are not working or the range of the monitoring device(s) is exceeded, other methods approved by EPA in the flare monitoring plan required by paragraph (h)(5) of this section shall be used to determine volumetric flow of the gas which shall then be used to calculate SO 2 emissions. In quarterly reports, sources shall indicate when other methods are used; or
(B) Use parameters and methods approved by EPA in the flare monitoring plan required by paragraph (h)(5) of this section to calculate the volumetric flows of the gas, in SCFH.
(3) Flare concentration monitoring: (i) Within 365 days after receiving EPA approval of the flare monitoring plan required by paragraph (h)(5) of this section, each facility named in paragraph (a) of this section shall determine the total sulfur concentration of the gas stream to the flare(s) using either continuous total sulfur analyzers or grab or integrated sampling with lab analysis, as described in the following paragraphs:
(A) Continuous total sulfur concentration monitoring. If a facility chooses to use continuous total sulfur concentration monitoring, the following requirements apply:
( 1 ) The facility shall install and calibrate, and, thereafter, calibrate, maintain and operate, a continuous total sulfur concentration monitoring system capable of measuring the total sulfur concentration of the gas stream to each flare. Continuous monitoring shall occur at a location or locations that are representative of the gas combusted in the flare and be capable of measuring the normally expected range of total sulfur in the gas stream to the flare. The concentration monitoring system shall require more than one concentration monitoring device or concentration measurements at more than one location if one monitor cannot measure the total sulfur concentration to each flare. Total sulfur concentration shall be reported as H 2 S or SO 2 in ppm. In cases when the total sulfur analyzer or analyzers are not working or the concentration of the total sulfur exceeds the range of the analyzer(s), other methods, approved by EPA in the flare monitoring plan required by paragraph (h)(5) of this section, shall be used to determine total sulfur concentrations, which shall then be used to calculate SO 2 emissions. In quarterly reports, sources shall indicate when these other methods are used.
( 2 ) The total sulfur analyzer(s) shall achieve a temporal sampling resolution of at least one (1) concentration measurement per 15 minutes, meet the requirements expressed in the definition of “hourly average” in paragraph (c)(14) of this section, be installed, certified (on a concentration basis), and operated in accordance with 40 CFR part 60, Appendix B, Performance Specification 5, and be subject to and meet the quality assurance and quality control requirements (on a concentration basis) of 40 CFR part 60, Appendix F.
( 3 ) Each affected facility named in paragraph (a) of this section shall notify the Air Program Contact at EPA's Montana Operations Office, Federal Building, 10 West 15th Street, Suite 3200, Helena, MT 59626, in writing of each Relative Accuracy Test Audit a minimum of 25 working days prior to the actual testing.
(B) Grab or integrated total sulfur concentration monitoring: If a facility chooses grab or integrated sampling instead of continuous total sulfur concentration monitoring, the facility shall comply with the methods specified in either paragraph (h)(3)(i)(B)( 1 ) (“Grab Sampling”) or (h)(3)(B)(i)(B)( 2 ) (“Integrated Sampling”), and the requirements of paragraphs (h)(3)(i)(B)( 3 ) (“Sample Analysis”), (h)(3)(i)(B)( 4 ) (“Exemptions”), and (h)(3)(i)(B)( 5 ) (“Missing or Unanalyzed Sample”) of this section, as follows:
( 1 ) Grab Sampling. Each facility that chooses to use grab sampling shall meet the following requirements: if the flow rate of the gas stream to the flare in any consecutive 15-minute period continuously exceeds 0.5 feet per second (fps) and the water seal monitoring device, if any, indicates that flow is going to the flare, a grab sample shall be collected within 15 minutes. The grab sample shall be collected at a location that is representative of the gas combusted in the flare. Thereafter, the sampling frequency shall be one (1) grab sample every three (3) hours, which shall continue until the velocity of the gas stream going to the flare in any consecutive 15-minute period is continuously 0.5 fps or less. Samples shall be analyzed according to paragraph (h)(3)(i)(B)( 3 ) of this section. The requirements of this paragraph (h)(3)(i)(B)( 1 ) shall apply to each flare at a facility for which the sampling threshold is exceeded.
( 2 ) Integrated Sampling. Each facility that chooses to use integrated sampling shall meet the following requirements: if the flow rate of the gas stream to the flare in any consecutive 15-minute period continuously exceeds 0.5 feet per second (fps) and the water seal monitoring device, if any, indicates that flow is going to the flare, a sample shall be collected within 15 minutes. The sample shall be collected at a location that is representative of the gas combusted in the flare. The sampling frequency, thereafter, shall be a minimum of one (1) aliquot for each 15-minute period until the sample container is full, or until the end of a 3-hour period is reached, whichever comes sooner. Within 30 minutes thereafter, a new sample container shall be placed in service, and sampling on this frequency, and in this manner, shall continue until the velocity of the gas stream going to the flare in any consecutive 15-minute period is continuously 0.5 fps or less. Samples shall be analyzed according to paragraph (h)(3)(i)(B)( 3 ) of this section. The requirements of this paragraph (h)(3)(i)(B)( 2 ) shall apply to each flare at a facility for which the sampling threshold is exceeded.
( 3 ) Samples shall be analyzed using ASTM Method D4468-85 (Reapproved 2000) “Standard Test Method for Total Sulfur in Gaseous Fuels by Hydrogenolysis and Rateometric Colorimetry,” (incorporated by reference, see paragraph (j) of this section) ASTM Method D5504-01 (Reapproved 2006) “Standard Test Method for Determination of Sulfur Compounds in Natural Gas and Gaseous Fuels by Gas Chromatography and Chemiluminescence,” (incorporated by reference, see paragraph (j) of this section) or 40 CFR part 60, Appendix A-5, Method 15A “Determination of Total Reduced Sulfur Emissions From the Sulfur Recovery Plants in Petroleum Refineries.” Total sulfur concentration shall be reported as H 2 S or SO 2 in ppm.
( 4 ) Exemptions. For facilities using a sampling method specified in either paragraph (h)(3)(i)(B)( 1 ) (“Grab Sampling”) or (h)(3)(i)(B)( 2 ) (“Integrated Sampling”) of this section, obtaining a sample is not required if flaring is a result of a catastrophic or other unusual event, including a major fire or an explosion at the facility, such that collecting a sample at the EPA-approved location during the relevant period is infeasible or constitutes a safety hazard, provided that the owner or operator shall collect a sample at an alternative location if feasible, safe, and representative of the flaring event. The owner or operator shall demonstrate to EPA that it was infeasible or unsafe to collect a sample or to collect a sample at the sampling location approved by EPA in the flare monitoring plan required by paragraph (h)(5) of this section. The owner or operator shall also demonstrate to EPA that any sample collected at an alternative location is representative of the flaring incident. If a facility experiences ongoing difficulties collecting grab or integrated samples in accordance with its flare monitoring plan approved by EPA pursuant to paragraph (h)(5) of this section, EPA may require the facility to revise its flare monitoring plan and use continuous total sulfur concentration monitoring as described in paragraph (h)(3)(i)(A) of this section or other reliable method to determine total sulfur concentrations of the gas stream to the flare.
( 5 ) Missing or Unanalyzed Samples. For facilities using a sampling method specified in either paragraph (h)(3)(i)(B)( 1 ) (“Grab Sampling”) or (h)(3)(i)(B)( 2 ) (“Integrated Sampling”) of this section, if a required sample is not obtained or analyzed for any reason, other methods approved by EPA in the flare monitoring plan required by paragraph (h)(5) of this section shall be used to determine total sulfur concentrations, which shall then be used to calculate SO 2 emissions. In quarterly reports, sources shall indicate when these other methods are used.
( 6 ) Reporting. For facilities using a sampling method specified in either paragraph (h)(3)(i)(B)( 1 ) (“Grab Sampling”) or (h)(3)(i)(B)( 2 ) (“Integrated Sampling”) of this section, since normally only one (1) sample per flare will be analyzed for a 3-hour period, the total sulfur concentration of a sample obtained during a given 3-hour period shall be substituted for each hour of such 3-hour period. If integrated sampling for a flare produces more than one (1) sample container during a 3-hour period, and the gas in each container is analyzed separately, the concentrations for the containers shall be averaged. For that flare, the resulting average shall be substituted for each hour of the 3-hour period during which the sampling occurred. The substituted hourly total sulfur concentrations determined per this paragraph shall be used to determine hourly emissions from the flare.
(ii) Each facility named in paragraph (a) of this section that does not certify that only natural gas or an inert gas is used for both the pilot gas and purge gas shall determine the H 2 S concentration of each pilot gas and purge gas stream for which natural gas or inert gas is not used by one of the following methods:
(A) Measure the H 2 S concentration of the gas by continuous H 2 S analyzer. The H 2 S concentration analyzer(s) shall achieve a temporal sampling resolution of at least one (1) concentration measurement per three (3) minutes, meet the requirements expressed in the definition of “hourly average” in paragraph (c)(14) of this section, be installed, certified (on a concentration basis), and operated in accordance with 40 CFR part 60, Appendix B, Performance Specification 2, and be subject to and meet the quality assurance and quality control requirements (on a concentration basis) of 40 CFR part 60, Appendix F. In cases where the H 2 S analyzer or analyzers are not working or the H 2 S concentration exceeds the range of the analyzer(s), other methods approved by EPA in the flare monitoring plan required by paragraph (h)(5) of this section shall be used to determine the H 2 S concentration of the gas, which shall then be used to calculate SO 2 emissions. In quarterly reports, sources shall indicate when other methods are used; or
(B) Use methods approved by EPA as part of the facility's flare monitoring plan required by paragraph (h)(5) of this section to estimate the H 2 S concentration of the gas.
(4) Calculation of SO 2 emissions from flares. Methods for calculating hourly and 3-hour SO 2 emissions from flares shall be submitted to EPA as part of the flare monitoring plan required by paragraph (h)(5) of this section. Following approval by EPA, such methods shall be followed for calculating hourly and 3-hour SO 2 emissions from a facility's flare(s).
(5) By October 20, 2008, each facility named in paragraph (a) of this section shall submit a flare monitoring plan. Each flare monitoring plan shall include, at a minimum, the following:
(i) A facility plot plan showing the location of each flare in relation to the general plant layout;
(ii) Drawing(s) with dimensions, preferably to scale, and an as-built process flow diagram of the flare(s) identifying major components, such as flare header, flare stack, flare tip(s) or burner(s), purge gas system, pilot gas system, water seal, knockout drum, and molecular seal;
(iii) A representative flow diagram showing the interconnections of the flare system(s) with vapor recovery system(s), process units, and other equipment as applicable;
(iv) A complete description of the gas flaring process for an integrated gas flaring system that describes the method of operation of the flares;
(v) A complete description of the vapor recovery system(s) which have interconnection to a flare, such as compressor description(s); design capacities of each compressor and the vapor recovery system; and the method currently used to determine and record the amount of vapors recovered;
(vi) A complete description of the proposed method to monitor, determine, and record the total volume and total sulfur concentration of gases combusted in the flare, including drawing(s) with dimensions, preferably to scale, showing the following information for the proposed flare gas stream monitoring systems:
(A) The locations to be used for all monitoring and sampling, including, but not limited to: Flare flow monitors, total sulfur analyzers, concentration integrated sampling, concentration grab sampling, water seal monitoring devices, pilot and purge gas flow monitors, and pilot and purge gas concentration monitors;
(vii) A description of the method(s) used to determine, and reasoning behind, all monitoring and sampling locations;
(viii) The following information regarding pilot gas and purge gas for each flare:
(A) Type(s) of gas used;
(B) A complete description of the monitor(s) to be used, or the other parameters that will be used and monitored, to determine volumetric flows of the pilot gas and purge gas streams for which natural gas or inert gas is not used; and
(C) A complete description of the analyzer(s) to be used to determine, or other methods that will be used to estimate, the H 2 S concentrations in the pilot gas and purge gas streams for which natural gas or inert gas is not used;
(ix) A detailed description of manufacturer's specifications, including, but not limited to, make, model, type, range, precision, accuracy, calibration, maintenance, quality assurance procedure, and any other relevant specifications and information referenced in paragraphs (h)(2) and (3) of this section for all existing and proposed flow monitoring devices and total sulfur analyzers;
(x) The following information if grab or integrated sampling is used:
(A) A complete description of proposed analytical and sampling methods if grab or integrated sampling methods will be used for determining the total sulfur concentration of the gas stream going to the flare;
(B) A detailed description of manufacturer's specifications, including, but not limited to, make, model, type, maintenance, and quality assurance procedures for the integrated sampling device, if used; and
(C) A complete description of the proposed method to alert personnel designated to collect samples that the trigger for collecting a sample has occurred;
(xi) A complete description of the methods to be used to estimate flare emissions when any flare, pilot gas, or purge gas volumetric flow monitoring devices, total sulfur analyzers, or grab or integrated sampling methods, or pilot gas or purge gas H 2 S analyzers are not working or available, or the operating range of the monitors or analyzers is exceeded;
(xii) A complete description of the proposed data recording, collection, and management system and any other relevant specifications and information referenced in paragraphs (h)(2) and (3) of this section for each flare monitoring system;
(xiii) The following information for each flare using a water seal monitoring device:
(A) A detailed description of manufacturer's specifications, including, but not limited to, make, model, type, maintenance, and quality assurance procedures;
(B) A complete description of the proposed methods to determine that the water seal is no longer intact and flow is going to the flare, and the data used to establish, and reasoning behind, these methods;
(xiv) A schedule for the installation and operation of each flare monitoring system consistent with the deadline in paragraphs (h)(2) and (h)(3) of this section; and
(xv) A complete description of the methods to be used for calculating hourly and 3-hour SO 2 emissions from flares.
(6) Thirty (30) days prior to installing any continuous monitor or integrated sampler pursuant to paragraphs (h)(2) and (3) of this section, each facility named in paragraph (a) of this section shall submit for EPA review a quality assurance/quality control (QA/QC) plan for each monitor or sampler being installed.
(i) [Reserved]
(j) Incorporation by reference. (1) The materials listed in this paragraph are incorporated by reference in the corresponding paragraphs noted. These incorporations by reference are approved by the Director of the Federal Register in accordance with 5 U.S.C. 552(a) and 1 CFR part 51. These materials are incorporated as they exist on the date of the approval, and notice of any change in these materials will be published in the Federal Register. The materials are available for purchase at the corresponding address noted below, and all are available for inspection at the National Archives and Records Administration (NARA) and at the Air Program, EPA, Region 8, 1595 Wynkoop Street, Denver, CO. For information on the availability of this material at NARA, call 202-741-6030, or go to: http://www.archives.gov/federal_register/code_of_federal_regulations/ibr_locations.html.
(2) The following materials are available for purchase from the following address: American Society for Testing and Materials (ASTM), 100 Barr Harbor Drive, Post Office Box C700, West Conshohocken, PA 19428-2959, www.astm.org , or by calling (610) 832-9585.
(i) ASTM Method D4468-85 (Reapproved 2000), Standard Test Method for Total Sulfur in Gaseous Fuels by Hydrogenolysis and Rateometric Colorimetry, IBR approved for paragraph (h)(3)(i)(B)( 3 ) of this section.
(ii) ASTM Method D4810-06, Standard Test Method for Hydrogen Sulfide in Natural Gas Using Length-of-Stain Detector Tubes, IBR approved for paragraphs (f)(3)(ii)(B), (g)(4)(ii)(C), and (g)(5)(ii)(C) of this section.
(ii) ASTM Method D5504-01 (Reapproved 2006), Standard Test Method for Determination of Sulfur Compounds in Natural Gas and Gaseous Fuels by Gas Chromatography IBR approved for paragraph (h)(3)(i)(B)( 3 ) of this section.
§ 52.1393   Interstate transport requirements.
(a) The State of Montana added the Interstate Transport Rule Declaration to the State SIP, State of Montana Air Quality Control Implementation Plan, Volume I, Chapter 9, to satisfy the requirements of Clean Air Act Section 110(a)(2)(D)(i) for the 8-hour ozone and PM 2.5 NAAQS promulgated in July 1997. The Montana Interstate Transport Rule Declaration, adopted and effective on the same date of February 12, 2007, was submitted to EPA on April 16, 2007. The April 16, 2007 Governor's letter included as an attachment a set of dated replacement pages for the Montana Interstate Transport Rule Declaration. The new set of pages were sent as replacement for the set of undated pages submitted earlier with the February 12, 2007 Record of Adoption package. In a May 10, 2007 e-mail to Domenico Mastrangelo, EPA, Debra Wolfe, of the Montana Department of Environmental Quality, confirmed February 12, 2007 as the adoption/effective date for the Montana Interstate Transport Rule Declaration.
(b) On February 10, 2010, Montana Governor Brian Schweitzer submitted a letter certifying, in part, that Montana's SIP is adequate to meet the interstate transport requirements of CAA section 110(a)(2)(D)(i)(I) for the 2006 PM 2.5 NAAQS.
(c) EPA is approving both elements of CAA section 110(a)(2)(D)(i)(I) for the 2008 ozone NAAQS, which was submitted to EPA on January 3, 2013.
(d) EPA is approving the Montana 2012 PM 2.5 NAAQS Infrastructure Certification, submitted to EPA on December 17, 2015, for both elements of CAA section 110(a)(2)(D)(i)(I) for the 2012 PM 2.5 NAAQS.
(e) EPA is approving the Montana 2010 SO 2 NAAQS Infrastructure Certification, submitted to EPA on July 15, 2013, for both elements of CAA section 110(a)(2)(D)(i)(I) for the 2010 SO 2 NAAQS.
§ 52.1394   Section 110(a)(2) infrastructure requirements.
(a) On December 22, 2009, David L. Klemp, Bureau Chief, Air Resources Management Bureau, of the Montana Department of Environmental Quality submitted a certification letter which provides the State of Montana's SIP provisions which meet the requirements of CAA Section 110(a)(1) and (2) relevant to the 1997 Ozone NAAQS.
(b) On February 10, 2010, Brian Schweitzer, Governor, State of Montana, submitted a certification letter which provides the State of Montana's SIP provisions which meet the requirements of CAA section 110(a)(1) and (2), elements (A), (B), (C) with respect to the requirement to have a minor NSR program that addresses PM 2.5 ; (E)(i), (E)(iii), (F), (G), (H), (J) with respect to the requirements of sections 121 and 127, (K), (L), and (M).
§ 52.1395   Smoke management plan.
The Department considers smoke management techniques for agriculture and forestry management burning purposes as set forth in 40 CFR 51.308(d)(3)(v)(E). The Department considers the visibility impact of smoke when developing, issuing, or conditioning permits and when making dispersion forecast recommendations through the implementation of Title 17, Chapter 8, subchapter 6, ARM, Open Burning.
§ 52.1396   [Reserved]