CHAPTER 123. STANDARDS FOR CONTAMINANTS

FUGITIVE EMISSIONS

Sec.


123.1.    Prohibition of certain fugitive emissions.
123.2.    Fugitive particulate matter.

PARTICULATE MATTER EMISSIONS


123.11.    Combustion units.
123.12.    Incinerators.
123.13.    Processes.
123.14.    Outdoor wood-fired boilers.

SULFUR COMPOUND EMISSIONS


123.21.    General.
123.22.    Combustion units.
123.23.    Byproduct coke oven gas.
123.24.    Primary zinc smelters.
123.25.    Monitoring requirements.

ODOR EMISSIONS


123.31.    Limitations.

VISIBLE EMISSIONS


123.41.    Limitations.
123.42.    Exceptions.
123.43.    Measuring techniques.
123.44.    Limitations of visible fugitive air contaminants from operation of any coke oven battery.
123.45.    Alternative opacity limitations.
123.46.    Monitoring requirements.

NITROGEN COMPOUND EMISSIONS


123.51.    Monitoring requirements.

NOx ALLOWANCE REQUIREMENTS


123.101.    Purpose.
123.102.    Source NOx allowance requirements and NOx allowance control period.
123.103.    General NOx allowance provisions.
123.104.    Source authorized account representative requirements.
123.105.    NATS provisions.
123.106.    NOx allowance transfer protocol.
123.107.    NOx allowance transfer procedures.
123.108.    Source emissions monitoring requirements.
123.109.    Source emissions reporting requirements.
123.110.    Source compliance requirements.
123.111.    Failure to meet source compliance requirements.
123.112.    Source operating permit provision requirements.
123.113.    Source recordkeeping requirements.
123.114.    General NOx allocation provisions.
123.115.    Initial NOx allowance NOx allocations.
123.116.    Source opt-in provisions.
123.117.    New NOx affected source provisions.
123.118.    Emission reduction credit provisions.
123.119.    Bonus NOx allowance awards.
123.120.    Audit.
123.121.    NOx Allowance Program transition.

STANDARDS FOR CONTAMINANTS
MERCURY EMISSIONS


123.201.    [Reserved].
123.202.    [Reserved].
123.203.    [Reserved].
123.204.    [Reserved].
123.205.    [Reserved].
123.206.    [Reserved].
123.207.    [Reserved].
123.208.    [Reserved].
123.209.    [Reserved].
123.210.    [Reserved].
123.211.    [Reserved].
123.212.    [Reserved].
123.213.    [Reserved].
123.214.    [Reserved].
123.215.    [Reserved].

Cross References

   This chapter cited in 25 Pa. Code §  77.455 (relating to air pollution control plan); 25 Pa. Code §  77.575 (relating to air resources protection); 25 Pa. Code §  87.66 (relating to air pollution control plan); 25 Pa. Code §  87.137 (relating to air resources protection); 25 Pa. Code §  88.48 (relating to air pollution control plan); 25 Pa. Code §  88.114 (relating to air resources protection); 25 Pa. Code §  88.205 (relating to air resources protection); 25 Pa. Code §  88.317 (relating to air resources protection); 25 Pa. Code §  88.492 (relating to minimum requirements for reclamation and operation plan); 25 Pa. Code §  89.13 (relating to air pollution control plan); 25 Pa. Code §  89.64 (relating to air resources protection); 25 Pa. Code §  90.44 (relating to air pollution control plan); 25 Pa. Code §  90.149 (relating to air resources protection); 25 Pa. Code §  139.52 (relating to monitoring methods and techniques); and 25 Pa. Code §  139.101 (relating to general requirements).

FUGITIVE EMISSIONS


§ 123.1. Prohibition of certain fugitive emissions.

 (a)  No person may permit the emission into the outdoor atmosphere of a fugitive air contaminant from a source other than the following:

   (1)  Construction or demolition of buildings or structures.

   (2)  Grading, paving and maintenance of roads and streets.

   (3)  Use of roads and streets. Emissions from material in or on trucks, railroad cars and other vehicular equipment are not considered as emissions from use of roads and streets.

   (4)  Clearing of land.

   (5)  Stockpiling of materials.

   (6)  Open burning operations.

   (7)  Blasting in open pit mines. Emissions from drilling are not considered as emissions from blasting.

   (8)  Coke oven batteries, provided the fugitive air contaminants emitted from any coke oven battery comply with the standards for visible fugitive emissions in § §  123.44 and 129.15 (relating to limitations of visible fugitive air contaminants from operation of any coke oven battery; and coke pushing operations).

   (9)  Sources and classes of sources other than those identified in paragraphs (1)—(8), for which the operator has obtained a determination from the Department that fugitive emissions from the source, after appropriate control, meet the following requirements:

     (i)   The emissions are of minor significance with respect to causing air pollution.

     (ii)   The emissions are not preventing or interfering with the attainment or maintenance of an ambient air quality standard.

 (b)  An application form for requesting a determination under either subsection (a)(9) or §  129.15(c) is available from the Department. In reviewing these applications, the Department may require the applicant to supply information including, but not limited to, a description of proposed control measures, charac-teristics of emissions, quantity of emissions and ambient air quality data and analysis showing the impact of the source on ambient air quality. The applicant is required to demonstrate that the requirements of subsections (a)(9) and (c) and §  123.2 (relating to fugitive particulate matter) or of the requirements of §  129.15(c) have been satisfied. Upon such demonstration, the Department will issue a determination, in writing, either as an operating permit condition, for those sources subject to permit requirements under the act, or as an order containing appropriate conditions and limitations.

 (c)  A person responsible for any source specified in subsections (a)(1)—(7) or (9) shall take all reasonable actions to prevent particulate matter from becoming airborne. These actions include, but not be limited to, the following:

   (1)  Use, where possible, of water or chemicals for control of dust in the demolition of buildings or structures, construction operations, the grading of roads or the clearing of land.

   (2)  Application of asphalt, oil, water or suitable chemicals on dirt roads, material stockpiles and other surfaces which may give rise to airborne dusts.

   (3)  Paving and maintenance of roadways.

   (4)  Prompt removal of earth or other material from paved streets onto which earth or other material has been transported by trucking or earth moving equipment, erosion by water, or other means.

 (d)  The requirements contained in subsection (a) and §  123.2 do not apply to fugitive emissions arising from the production of agricultural commodities in their unmanufactured state on the premises of the farm operation.

Source

   The provisions of this §  123.1 adopted September 10, 1971, effective September 11, 1971, 1 Pa.B. 1804; amended March 3, 1972, effective March 20, 1972, 2 Pa.B. 383; amended August 12, 1977, effective August 29, 1977, 7 Pa.B. 2251. Immediately preceding text appears at serial pages (4620) and (24610).

Notes of Decisions

   Agency Authority

   Although the Department of Environmental Resources under the Air Pollution Control Act (35 P. S. §  4001 et seq.) had been granted specific authority by the Legislature to regulate ‘‘air contamination sources’’ producing ‘‘air pollution’’ that includes obnoxious odors, nowhere was there any grant of authority to the Public Utility Commission, either directly or indirectly, to regulate air pollution emanating from a public utility. Country Place Waste Treatment Co. v. Pennsylvania Public Utility Commission, 654 A.2d 72 (Pa. Cmwlth. 1995).

   Application Properly Denied

   The Department was required to deny an application for reactivation of beehive coke ovens, regardless of economic consequences, when the application did not provide information which would show that the ovens would meet the limitations applicable to fugitive emissions, and constitutional rights are not violated even though there is no known method to operate beehive coke ovens in compliance with this title. Rochez Brothers Inc. v. Department of Environmental Resources, 334 A.2d 790 (Pa. Cmwlth. 1975).

   Burden of Proof

   Testimony by the environmental group’s president that the air was polluted (that is, ‘‘fuming’’ resulted from the reaction process used to treat waste at the industrial processors facility) was not credible on the issues relating to the existence or cause of air quality problems as would shift the burden of proof to the Department of Environmental Resources to justify the issuance of the solid waste disposal permit. Concerned Citizens of Yough, Inc. v. Department of Environmental Resources, 639 A.2d 1265 (Pa. Cmwlth. 1994).

   The Commonwealth need not prove that the fugitive dust emissions in question caused or contributed to a condition of air pollution because the determination that such emissions cause or contribute to a condition of air pollution had already been made at the time the section was promulgated, and the section is reasonably understandable and specific. Department of Environmental Resources v. Locust Point Quarries, Inc., 396 A.2d 1205 (Pa. 1979).

   Clearing of Land

   Environmental Hearing Board did not err in finding asphalt plant operator’s extracting soil down to bedrock to prepare area for blasting was not exempt from ‘‘clearing of land,’’ Department of Environmental Protection defined clearing of land as the removal of trees, brush and surface vegetation and not the removal of overburden down to bedrock. Eureka Stone Quarry v. Dep’t of Envtl. Protection, 957 A.2d 337, 348 (Pa. Cmwlth. 2008).

   Construction

   Since §  123.2 (relating to fugitive particulate matter) applies only to the nine exemptions listed in (a)(1)—(9), the two sections do not overlap and either one can stand alone as a basis for a violation. Medusa Corp. v. Department of Environmental Resources, 415 A.2d 105 (Pa. Cmwlth. 1980).

   Criminal Prosecution

   To prove a criminal violation of this section, as modified by §  123.13 (relating to processes), scientific evidence must be introduced proving beyond a reasonable doubt that the offensive fugitive emissions exceeded the permissible maximum set forth in §  123.12 (relating to incinerators). Department of Environmental Resources v. Locust Point Quarries Inc., 367 A.2d 392 (Pa. Cmwlth. 1976).

   Evidence

   To properly challenge the reasonableness of this section, evidence must be presented to establish that the section will not aid in reaching national ambient air quality standards and that the proscribed activity is insignificant as a cause of air pollution. Department of Environmental Resources v. Locust Point Quarries, Inc., 396 A.2d 1205 (Pa. 1979).

   A conviction for violation of this section cannot be sustained absent sufficient visual and/or scientific evidence to establish that the quarry dust observed by Department agents was such as to constitute air pollution as defined by the Air Pollution Control Act. Commonwealth v. Locust Point Quarries Inc., 72 Pa. D. & C.2d 700 (1975).

   Fugitive Emissions

   A fugitive emission is an emission of an air contaminant in a specific manner and it includes particulate matter, sulfur compounds, odor and visible emissions if emitted other than through a flue. Department of Environmental Resources v. Locust Point Quarries, Inc., 396 A.2d 1205 (Pa. 1979).

   General Comment

   This section was intended to stand alone and be construed independently of §  123.13 (relating to processes). Department of Environmental Resources v. Locust Point Quarries, Inc., 396 A.2d 1205 (Pa. 1979).

   Minor Significance

   The comment by the Environmental Hearing Board that the operator failed to invoke the ‘‘minor significance’’ exception of (a)(9) was proper because the exception existed throughout the relevant time period of 1973 to 1976, and the procedural provisions added by a 1977 amendment were immaterial. Medusa Corp. v. Department of Environmental Resources, 415 A.2d 105 (Pa. Cmwlth. 1980).

   A rock quarry was not a source of minor significance within the meaning of §  127.14 (relating to exemptions) if nothing in the record supported such a determination and the DER had not so determined. Mignatti Construction Co., Inc. v. Environmental Hearing Board, 411 A.2d 860 (Pa. Cmwlth. 1980).

   Review

   A request for a grace period for compliance with a temporary variance did not have a res judicata effect on a subsequent request for an exemption from emission control requirements under this provision, since there was no identity of the thing sued for. Bethlehem Steel Corporation v. Department of Environmental Resources, 390 A.2d 1383 (Pa. Cmwlth. 1978).

   On appeal from the Department’s refusal to grant applicant permission to reactivate certain coke ovens, if the appellant did not show that the oven would meet the limitations in this title, but showed only the ‘‘dire need’’ for the coke to be produced, the scope of review is limited to whether constitutional rights were violated, an error of law committed, or any necessary finding of fact was not supported by the evidence. Rochez Brothers, Inc. v. Department of Environmental Resources, 334 A.2d 790 (Pa. Cmwlth. 1975).

Cross References

   This section cited in 25 Pa. Code §  77.108 (relating to permit for small noncoal operations); 25 Pa. Code §  121.8 (relating to compliance responsibilities); 25 Pa. Code §  123.2 (relating to fugitive particulate matter); 25 Pa. Code §  123.42 (relating to exceptions); 25 Pa. Code §  129.15 (relating to coke pushing operations); and 25 Pa. Code §  264.521 (relating to design and operating standards).

§ 123.2. Fugitive particulate matter.

 A person may not permit fugitive particulate matter to be emitted into the outdoor atmosphere from a source specified in §  123.1(a)(1)—(9) (relating to prohibition of certain fugitive emissions) if the emissions are visible at the point the emissions pass outside the person’s property.

Source

   The provisions of this §  123.2 adopted September 10, 1971, effective September 11, 1971, 1 Pa.B. 1804; amended March 3, 1972, effective March 20, 1972, 2 Pa.B. 383; amended August 12, 1983, effective August 13, 1983, 13 Pa.B. 2478. Immediately preceding text appears at serial page (60646).

Notes of Decisions

   Evidence

   Visual evidence that dust emission left quarry property without witness as to the precise moment when fugitive dust escaped from the property was not proper grounds for dismissal of a violation as de minimis. Scurfield Coal, Inc. v. Commonwealth, 582 A.2d 694 (Pa. Cmwlth. 1990).

   Facility Operations

   This section which requires quarry owner to prevent emission into the atmosphere of particulate matter encompasses material stockpiled in both active and inactive operations, since the detriment to the public is the same. Eureka Stone Quarry, Inc. v. Commonwealth, 544 A.2d 1129 (Pa. Cmwlth. 1988).

   Prevention

   Quarry owner has an active duty to prevent particulate matter from visibly escaping into the atmosphere onto another’s property, which includes a responsibility to provide an adequate suppression system. Eureka Stone Quarry, Inc. v. Commonwealth, 544 A.2d 1129 (Pa. Cmwlth. 1988).

   Testimony of an air quality specialist who visited the defendant’s quarry and viewed dust blowing into the air from actual stone crushing areas, conveying areas, stockpiles and haulage ways was sufficient to prove defendant caused the prohibited emissions to be emitted into the atmosphere outside of its own property. Eureka Stone Quarry, Inc. v. Commonwealth, 544 A.2d 1129 (Pa. Cmwlth. 1988).

   This section which requires a quarry owner to prevent emission into the atmosphere of particulate matter encompasses material stockpiled in both active and inactive operations, since the detriment to the public is the same. Eureka Stone Quarry, Inc. v. Commonwealth, 544 A.2d 1129 (Pa. Cmwlth. 1988).

   Quarry owner has an active duty to prevent particulate matter from visibly escaping into the atmosphere onto another’s property, which includes a responsibility to provide an adequate suppression system. Eureka Stone Quarry, Inc. v. Commonwealth, 544 A.2d 1129 (Pa. Cmwlth. 1988).

   Since this section applies only to the nine exemptions listed in §  123.1(a)(1)—(9) (relating to fugitive emissions), the two sections do not overlap and either one can stand alone as a basis for a violation. Medusa Corp. v. Department of Environmental Resources, 415 A.2d 105 (Pa. Cmwlth. 1980).

Cross References

   This section cited in 25 Pa. Code §  77.108 (relating to permit for small noncoal operations); 25 Pa. Code §  123.1 (relating to prohibition of certain fugitive emissions); and 25 Pa. Code §  264.521 (relating to design and operating standards).

PARTICULATE MATTER EMISSIONS


§ 123.11. Combustion units.

 (a)  A person may not permit the emission into the outdoor atmosphere of particulate matter from a combustion unit in excess of the following:

   (1)  The rate of 0.4 pound per million Btu of heat input, when the heat input to the combustion unit in millions of Btus per hour is greater than 2.5 but less than 50.

   (2)  The rate determined by the following formula:

   A = 3.6E-0.56

   where:

   A = Allowable emissions in pounds per million Btus of heat input,  and

   E = Heat input to the combustion unit in millions of Btus per hour,

   when E is equal to or greater than 50 but less than 600.

   (3)  The rate of 0.1 pound per million Btu of heat input when the heat input to the combustion unit in millions of Btus per hour is equal to or greater than 600.

 (b)  Allowable emissions under subsection (a) are graphically indicated in Appendix A.

Source

   The provisions of this §  123.11 adopted September 10, 1971, effective September 11, 1971, 1 Pa.B. 1804; amended March 3, 1972, effective March 20, 1972, 2 Pa.B. 383.

Notes of Decisions

   Impossibility

   There is no constitutional prohibition against imposition of civil penalties for failure to comply with technologically impossible standards, since the use of fines to spark technological development is reasonably related to the goal of reducing pollution. Department of Environmental Resources v. Pennsylvania Power Co. 416 A.2d 995 (Pa. 1980).

   Impossibility of performance is a defense in a contempt proceeding where an order of court ordering a power company to comply with the SO2 regulations was impossible of performance and where, under the present state of technology, the power company’s proposed use of higher smokestacks to control SO2 emissions was as close as the company could come to compliance with the regulations. Department of Environmental Resources v. Pennsylvania Power Company, 316 A.2d 96 (Pa. Cmwlth. 1974).

   Substantial Evidence

   Substantial evidence of a violation can be supplied by the violator itself and need not be independently produced by the Department. Department of Environmental Resources v. Pennsylvania Power Company, 384 A.2d 273 (Pa. Cmwlth. 1978).

Cross References

   This section cited in 25 Pa. Code §  121.8 (relating to compliance responsibilities); and 25 Pa. Code §  139.12 (relating to emissions of particulate matter).

§ 123.12. Incinerators.

 

   No person may permit the emission to the outdoor atmosphere of particulate matter from any incinerator, at any time, in such a manner that the particulate matter concentration in the effluent gas exceeds 0.1 grain per dry standard cubic foot, corrected to 12% carbon dioxide.

Source

   The provisions of this §  123.12 adopted September 10, 1971, effective September 11, 1971, 1 Pa.B. 1804; amended March 3, 1972, effective March 20, 1972, 2 Pa.B. 383.

Cross References

   This section cited in 25 Pa. Code §  121.8 (relating to compliance responsibilities); and 25 Pa. Code §  139.12 (relating to emissions of particulate matter).

§ 123.13. Processes.

 (a)  Subsections (b) and (c) apply to all processes except combustion units, incinerators and pulp mill smelt dissolving tanks.

 (b)  No person may permit the emission into the outdoor atmosphere of particulate matter from a process listed in the following table, at any time, either in excess of the rate calculated by the formula in paragraph (2) or in a manner that the concentration of particulate matter in the effluent gas exceeds .02 grains per dry standard cubic foot, whichever is greater:

   (1)  Table.

Process Factor, F
Process
(in pounds per ton)
Byproduct coke production: pushing operation1 (coke pushed)
Sole heated nonrecovery coke oven20 (coal charged/oven)
Carbon black manufacturing500 (product)
Charcoal manufacturing400 (product)
Paint manufacturing.05 (pigment handled)
Phosphoric acid manufacturing6 (P2 O5 produced)
Detergent drying30 (product)
Alfalfa dehydration30 (product)
Grain elevators (loading or unloading)90 (grain)
Grain screening and cleaning300 (grain)
Grain drying200 (product)
Meat smoking.01 (meat)
Ammonium nitrate manufacturing (granulator).1 (product)
Ferroalloy production furnace.3 (product)
Primary iron and/or steel making:
 Iron production100 (product)
  Sintering—windbox20 (dry solids feed)
  Steel production40 (product)
  Scarfing20 (product)
Primary lead production:
 Roasting.004 (ore feed)
 Sintering—windbox.2 (sinter)
 Lead reduction.5 (product)
Primary zinc production:
 Roasting3 (ore feed)
 Sintering—windbox2 (product)
 Zinc reduction10 (product)
Secondary aluminum production:
 Sweating50 (aluminum product)
 Melting and refining10 (aluminum feed)
Brass and bronze production (melting and refining)20 (product)
Iron foundry:
 Melting:
  Five tons per hour and less150 (iron)
  More than five tons per hour50 (iron)
 Sand handling20 (sand)
 Shake-out20 (sand)
Secondary lead smelting.5 (product)
Secondary magnesium smelting.2 (product)
Secondary zinc smelting:
 Sweating.01 (product)
 Refining.3 (product)
Asphaltic concrete production6 (aggregate feed)
Asphalt roofing manufacturing: (felt saturation).6 (asphalt used)
Portland cement manufacturing:
 Clinker production150 (dry solids feed)
 Clinker cooling50 (product)
Coal dry-cleaning2 (product)
Lime calcining200 (product)
Petroleum refining (catalytic cracking)40 (liquid feed)
Pressed, blown, and spun glass; glass production melting furnaces50 (Fill)

   (2)  Formula.A = .76E0.42

 where:A = Allowable emissions in pounds per hour. E = Emission index = F X W pounds per hour. F = Process factor in pounds per unit, and W = Production or charging rate in units per hour.

   The factor F shall be obtained from the table in paragraph (1). The units for F and W shall be compatible.

   (3)  Allowable emissions. Allowable emissions under this subsection are graphically indicated in Appendix B.

 (c)  For processes not listed in subsection (b)(1), including, but not limited to, coke oven battery waste heat stacks and autogeneous zinc coker waste heat stacks, the following apply:

   (1)  Prohibited emissions. No person may permit the emission into the outdoor atmosphere of particulate matter from a process not listed in subsection (b)(1) in a manner that the concentration of particulate matter in the effluent gas exceeds any of the following:

     (i)   .04 grain per dry standard cubic foot, when the effluent gas volume is less than 150,000 dry standard cubic feet per minute.

     (ii)   The rate determined by the following formula:A = 6000 E-1

   where: A = Allowable emissions in grains per dry standard cubic foot, and E = Effluent gas volume in dry standard cubic feet per minute,

   when E is equal to or greater than 150,000 but less than 300,000.

     (iii)   .02 grain per dry standard cubic foot, when the effluent gas volume is greater than 300,000 dry standard cubic feet per minute.

   (2)  Allowable emissions. Allowable emissions under this subsection are graphically indicated in Appendix C.

 (d)  No person may permit the emission into the outdoor atmosphere of particulate matter from kraft and soda pulp mill smelt dissolving tanks in excess of .2 lb/ton black liquor solids—dry basis.

Authority

   The provisions of this §  123.13 issued under section 1920-A of The Administrative Code of 1929 (71 P. S. §  510-20); and section 5 of the Air Pollution Control Act (35 P. S. §  4005); amended under section 5 of the Air Pollution Control Act (35 P. S. §  4005).

Source

   The provisions of this §  123.13 adopted September 10, 1971, effective September 11, 1971, 1 Pa.B. 1804; amended March 3, 1972, effective March 20, 1972, 2 Pa.B. 383; amended April 26, 1974, effective May 13, 1974, 4 Pa.B. 824; amended July 25, 1975, effective August 11, 1975, 5 Pa.B. 1916; amended July 23, 1976, effective August 9, 1976, 6 Pa.B. 1730; amended August 12, 1978, effective August 29, 1978, 8 Pa.B. 2251; amended September 26, 1980, effective September 27, 1980, 10 Pa.B. 3788; amended August 12, 1983, effective August 13, 1983, 13 Pa.B. 2478; amended May 6, 1988, effective May 7, 1988, 18 Pa.B. 2102. Immediately preceding text appears at serial pages (84509) to (84511).

Notes of Decisions

   Criminal Violation

   To prove a criminal violation of §  123.1, as modified by this section, scientific evidence must be introduced proving beyond a reasonable doubt that the offensive fugitive emissions exceeded the permissible maximum set forth in this section. Department of Environmental Resources v. Locust Point Quarries, Inc., 367 A.2d 392 (Pa. Cmwlth. 1976).

   Denial of Application

   The Department is required to deny an application for reactivation of beehive coke ovens, regardless of economic consequences, when the application does not provide any information which would show that the ovens would meet the limitations applicable to fugitive emissions and constitutional rights are not violated even though there is no known method to operate beehive coke ovens in compliance with the regulations. Rochez Brothers Inc. v. Department of Environmental Resources, 334 A.2d 790 (Pa. Cmwlth. 1975).

   Failure to Appeal

   Where the party is aggrieved by Department order requiring compliance with this section by a certain date, failure to appeal the order bars an attack on the order and the validity of the regulation on which it was predicated in a subsequent enforcement proceeding brought by the Department. Department of Environmental Resources v. Wheeling-Pittsburgh Steel Corp., 348 A.2d 765 (Pa. Cmwlth. 1975); affirmed in part remanded in part; 357 A.2d 320 (Pa. 1977); cert. denied 98 S. Ct. 514 (Pa. 1977).

   Process

   A quarry operation would appear to be included among those manufacturing processes outlined in this section but this interpretation does not preclude prosecution under another regulation restricting a distinct form of air contamination even though the same sources of contamination and the same contaminant are involved. Commonwealth v. Locust Point Quarries Inc., 72 Pa. D. & C.2d 700 (1975).

   A steel corporation which is granted an extension of time for compliance with the standards relating to particulate matter emissions may not attack the validity of the order or the regulations on which it was predicated in a subsequent enforcement proceeding, and the corporation does not have the right to trial by jury even though it seeks declaratory relief in its answer to the enforcement petition. Department of Environmental Resources v. Wheeling-Pittsburgh Steel Corp., 375 A.2d 320 (Pa. Cmwlth. 1977); 348 A.2d 765 (Pa. Cmwlth. 1975).

   Scope of Review

   On appeal from the Department’s refusal to grant applicant permission to reactivate certain coke ovens, where the appellant does not show that the oven would meet the limitations in this title but shows only the ‘‘dire need’’ for the coke to be produced, the scope of review is limited to whether constitutional rights were violated, an error of law committed or any necessary finding of fact not supported by the evidence. Rochez Brothers, Inc. v. Department of Environmental Resources, 334 A.2d 790 (Pa. Cmwlth. 1975).

Cross References

   This section cited in 25 Pa. Code §  121.8 (relating to compliance responsibilities); 25 Pa. Code §  129.15 (relating to coke pushing operations); and 25 Pa. Code §  139.12 (relating to emissions of particulate matter).

§ 123.14. Outdoor wood-fired boilers.

 (a)  Applicability. Beginning on October 2, 2010, this section applies to the following:

   (1)  A person, manufacturer, supplier or distributor who sells, offers for sale, leases or distributes an outdoor wood-fired boiler for use in this Commonwealth.

   (2)  A person who installs an outdoor wood-fired boiler in this Commonwealth.

   (3)  A person who purchases, receives, leases, owns, uses or operates an outdoor wood-fired boiler in this Commonwealth.

 (b)  Exemptions.

   (1)  This section does not apply to a person, manufacturer, supplier or distributor who sells, offers for sale, leases or distributes in this Commonwealth a non-Phase 2 outdoor wood-fired boiler if the person, manufacturer, supplier or distributor demonstrates the non-Phase 2 outdoor wood-fired boiler is intended for shipment and use outside of this Commonwealth.

   (2)  Subsections (c), (d) and (e) do not apply to a permanently installed outdoor wood-fired boiler that was installed prior to October 2, 2010, and is transferred to a new owner as a result of a real estate transaction.

   (3)  A person may not sell, offer for sale, distribute or lease a non-Phase 2 outdoor wood-fired boiler in this Commonwealth unless the outdoor wood-fired boiler was manufactured, distributed, purchased or leased and received in this Commonwealth before May 31, 2011.

     (i)   This exemption shall remain in effect until May 31, 2011.

     (ii)   A non-Phase 2 outdoor wood-fired boiler purchased during the sell-through period must meet the following requirements:

       (A)   Be installed a minimum of 150 feet from the nearest property line.

       (B)   Have a permanently attached stack that meets the following requirements:

         (I)   Extends a minimum of 10 feet above the ground.

         (II)   Is installed according to the manufacturer’s specifications.

 (c)  Phase 2 outdoor wood-fired boiler. Except as provided under subsection (b):

   (1)  A person may not sell, offer for sale, distribute or install an outdoor wood-fired boiler for use in this Commonwealth unless it is a Phase 2 outdoor wood-fired boiler.

   (2)  A person may not purchase, lease or receive an outdoor wood-fired boiler for use in this Commonwealth unless it is a Phase 2 outdoor wood-fired boiler.

 (d)  Setback requirements for new Phase 2 outdoor wood-fired boilers. A person may not install a new Phase 2 outdoor wood-fired boiler in this Commonwealth unless the boiler is installed a minimum of 50 feet from the nearest property line.

 (e)  Stack height requirements for new Phase 2 outdoor wood-fired boilers. A person may not install, use or operate a new Phase 2 outdoor wood-fired boiler in this Commonwealth unless the boiler has a permanently attached stack. The stack must meet both of the following requirements:

   (1)  Extend a minimum of 10 feet above the ground.

   (2)  Be installed according to the manufacturer’s specifications.

 (f)  Allowed fuels. A person that owns, leases, uses or operates an outdoor wood-fired boiler in this Commonwealth shall use only one or more of the following fuels:

   (1)  Clean wood.

   (2)  Wood pellets made from clean wood.

   (3)  Home heating oil, natural gas or propane that:

     (i)   Complies with all applicable sulfur limits.

     (ii)   Is used as a starter or supplemental fuel for dual-fired outdoor wood-fired boilers.

   (4)  Other types of fuel approved in writing by the Department upon receipt of a written request.

 (g)  Prohibited fuels. A person who owns, leases, uses or operates an outdoor wood-fired boiler in this Commonwealth may not burn a fuel or material in that outdoor wood-fired boiler other than those fuels listed under subsection (f).

 (h)  Applicable laws and regulatory requirements. A person may not use or operate an outdoor wood-fired boiler in this Commonwealth unless it complies with applicable Commonwealth, county and local laws and regulations adopted thereunder.

Authority

   The provisions of this §  123.14 issued under section 5(a)(1) of the Air Pollution Control Act (35 P. S. §  4005(a)(1).

Source

   The provisions of this §  123.14 adopted October 1, 2010, effective October 2, 2010, 40 Pa.B. 5571.

Cross References

   This section cited in 25 Pa. Code §  121.1 (relating to definitions).

SULFUR COMPOUND EMISSIONS


§ 123.21. General.

 (a)  This section applies to sources except those subject to other provisions of this article, with respect to the control of sulfur compound emissions.

 (b)  No person may permit the emission into the outdoor atmosphere of sulfur oxides from a source in a manner that the concentration of the sulfur oxides, expressed as SO2, in the effluent gas exceeds 500 parts per million, by volume, dry basis.

Source

   The provisions of this §  123.21 adopted September 10, 1971, effective September 11, 1971, 1 Pa.B. 1804; amended March 3, 1972, effective March 20, 1972, 2 Pa.B. 383.

§ 123.22. Combustion units.

 (a)  Nonair basin areas. Combustion units in nonair basin areas must conform with the following:

   (1)  General provision. A person may not permit the emission into the outdoor atmosphere of sulfur oxides, expressed as SO2, from a combustion unit in excess of the rate of 4 pounds per million Btu of heat input over a 1-hour period, except as provided in paragraph (4).

   (2)  Commercial fuel oil.

     (i)   Except as specified in subparagraphs (ii) and (iii), a person may not offer for sale, deliver for use, exchange in trade or permit the use of commercial fuel oil in nonair basin areas if the commercial fuel oil contains sulfur in excess of the applicable maximum allowable sulfur content set forth in the following tables:

Grades Commercial Fuel Oil
Maximum Allowable % Sulfur by
Weight through June 30, 2016
No. 2 and Lighter (viscosity less than or equal to 5.820cSt) 0.5
No. 4, No. 5, No. 6 and heavier (viscosity greater than 5.82cSt) 2.8


Maximum Allowable Sulfur Content Beginning July 1, 2016,
Expressed as Parts per Million (ppm) by Weight or Percentage by Weight


Grades Commercial Fuel Oil (Consistent with ASTM D396)
No. 2 and lighter oil 500 ppm
(0.05%)
No. 4 oil 2,500 ppm
(0.25%)
No. 5, No. 6 and heavier oil 5,000 ppm
(0.5%)

     (ii)   Commercial fuel oil that was stored in this Commonwealth by the ultimate consumer prior to July 1, 2016, which met the applicable maximum allowable sulfur content for commercial fuel oil through June 30, 2016, in subparagraph (i) at the time it was stored, may be used by the ultimate consumer in this Commonwealth on and after July 1, 2016.

     (iii)   Beginning July 1, 2016, the Department may temporarily suspend or increase the applicable maximum allowable sulfur content for a commercial fuel oil set forth in subparagraph (i) if the following occur:

       (A)   The Department receives a written request at the address specified in subsection (h) for a suspension or increase on the basis that compliant commercial fuel oil is not reasonably available in a nonair basin area. The request must include the following:

         (I)   The nonair basin county or counties for which the suspension or increase is requested.

         (II)   The reason compliant commercial fuel oil is not reasonably available.

         (III)   The duration of time for which the suspension or increase is requested and the justification for the requested duration.

       (B)   The Department determines that an insufficient quantity of compliant commercial fuel oil is reasonably available in the nonair basin area and that the circumstances leading to the insufficiency are due to events that could not have been reasonably foreseen or prevented and are not due to lack of prudent planning on the part of the transferor of the commercial fuel oil into or within the specified nonair basin area.

       (C)   The Department approves the request, in writing, prior to the transferor distributing the noncompliant commercial fuel oil into or within the specified nonair basin area.

     (iv)   The Department will limit a suspension or increase in the applicable maximum allowable sulfur content granted under subparagraph (iii) to the shortest duration in which adequate supplies of compliant commercial fuel oil can be made reasonably available, but in no case longer than 60 days from the date the Department grants the suspension or increase.

   (3)  Equivalency provision. Paragraph (2) does not apply to a person who uses equipment or a process, or to the owner or operator of an installation where equipment or a process is used, to reduce the sulfur emissions from the burning of a fuel with a higher sulfur content than that specified in paragraph (2). The emissions may not exceed those which would result from the use of commercial fuel oil that meets the applicable maximum allowable sulfur content specified in paragraph (2).

   (4)  Solid fossil fuel fired combustion units. Solid fossil fuel fired combustion units shall conform with the following:

     (i)   This paragraph applies to solid fossil fuel fired combustion units with a rated capacity greater than or equal to 250 million Btus of heat input per hour.

     (ii)   The owner of a solid fossil fuel fired combustion unit with a rated capacity of less than 250 million Btu heat input per hour may petition the Department for application of the limitations in this paragraph in lieu of the limitations in paragraph (1). Upon demonstration of installation of continuous monitoring equipment which complies with Chapter 139 (relating to sampling and testing) the Department will grant the petition.

     (iii)   No person subject to this paragraph may permit the emission into the outdoor atmosphere of sulfur oxides, expressed as SO2 from a combustion unit in excess of the rates set forth in the following table:

Allowable Pounds SO2 per
106 Btu Heat Input
Thirty-day running average not to be exceeded at any time 3.7
Daily average not to be exceeded more than 2 days in any running 30-day period 4.0
Daily average maximum not to be exceeded at any time 4.8

     (iv)   A combustion unit which does not meet the requirements of §  123.25 (relating to monitoring requirements) for installation and operation of continuous SO2 emission monitoring equipment shall be subject to the provisions of paragraph (1).

 (b)  Erie; Harrisburg; York; Lancaster; and Scranton, Wilkes-Barre air basins. Combustion units in these subject air basins must conform with the following:

 

   (1)  General provision. A person may not permit the emission into the outdoor atmosphere of sulfur oxides, expressed as SO2, from a combustion unit in excess of the rate of 4 pounds per million Btu of heat input over a 1-hour period, except as provided in paragraph (4).

   (2)  Commercial fuel oil.

     (i)   Except as specified in subparagraphs (ii) and (iii), a person may not offer for sale, deliver for use, exchange in trade or permit the use of commercial fuel oil in the subject air basins if the commercial fuel oil contains sulfur in excess of the applicable maximum allowable sulfur content set forth in the following tables:

Grades Commercial Fuel Oil
Maximum Allowable % Sulfur by
Weight through June 30, 2016
No. 2 and Lighter (viscosity less than or equal to 5.820cSt) 0.3
No. 4, No. 5, No. 6 and heavier (viscosity greater than 5.82cSt) 2.8

Maximum Allowable Sulfur Content Beginning July 1, 2016,
Expressed as Parts per Million (ppm) by Weight or Percentage by Weight


Grades Commercial Fuel Oil (Consistent with ASTM D396)
No. 2 and lighter oil 500 ppm
(0.05%)
No. 4 oil 2,500 ppm
(0.25%)
No. 5, No. 6 and heavier oil 5,000 ppm
(0.5%)

     (ii)   Commercial fuel oil that was stored in this Commonwealth by the ultimate consumer prior to July 1, 2016, which met the applicable maximum allowable sulfur content for commercial fuel oil through June 30, 2016, in subparagraph (i) at the time it was stored, may be used by the ultimate consumer in this Commonwealth on and after July 1, 2016.

     (iii)   Beginning July 1, 2016, the Department may temporarily suspend or increase the applicable maximum allowable sulfur content for a commercial fuel oil set forth in subparagraph (i) if the following occur:

       (A)   The Department receives a written request at the address specified in subsection (h) for a suspension or increase on the basis that compliant commercial fuel oil is not reasonably available in a subject air basin. The request must include the following:

         (I)   The subject air basin for which the suspension or increase is requested.

         (II)   The reason compliant commercial fuel oil is not reasonably available.

         (III)   The duration of time for which the suspension or increase is requested and the justification for the requested duration.

       (B)   The Department determines that an insufficient quantity of compliant commercial fuel oil is reasonably available in the air basin and that the circumstances leading to the insufficiency are due to events that could not have been reasonably foreseen or prevented and are not due to lack of prudent planning on the part of the transferor of the commercial fuel oil into or within the air basin.

       (C)   The Department approves the request, in writing, prior to the transferor distributing the noncompliant commercial fuel oil into or within the air basin.

     (iv)   The Department will limit a suspension or increase in the applicable maximum allowable sulfur content granted under subparagraph (iii) to the shortest duration in which adequate supplies of compliant commercial fuel oil can be made reasonably available, but in no case longer than 60 days from the date the Department grants the suspension or increase.

   (3)  Equivalency provision. Paragraph (2) does not apply to a person who uses equipment or a process, or to the owner or operator of an installation where equipment or a process is used, to reduce the sulfur emissions from the burning of a fuel with a higher sulfur content than that specified in paragraph (2). The emissions may not exceed those which would result from the use of commercial fuel oil that meets the applicable maximum allowable sulfur content specified in paragraph (2).

   (4)  Solid fossil fuel fired combustion units. Solid fossil fuel fired combustion units shall conform with the following:

     (i)   This paragraph applies to solid fossil fuel fired combustion units with a rated capacity greater than or equal to 250 million Btus of heat input per hour and to a solid fossil fuel fired combustion unit upon petition to and acceptance by the Department.

     (ii)   The owner of any solid fossil fuel fired combustion unit with a rated capacity of less than 250 million Btu heat input per hour may petition the Department for application of the limitations in this paragraph in lieu of the limitations in paragraph (1). Upon demonstration of installation of continuous monitoring equipment which complies with Chapter 139, the Department will grant the petition.

     (iii)   No person may permit the emission into the outdoor atmosphere of sulfur oxides, expressed as SO2, from a combustion unit, at any time, in excess of the rates set forth in the following table:

Allowable Pounds SO2 per
106 Btu Heat Input
Thirty-day running average not to be exceeded at any time 3.7
Daily average not to be exceeded more than 2 days in any running 30-day period 4.0
Daily average maximum not to be exceeded at any time 4.8

     (iv)   A combustion unit which does not meet the requirements of §  123.25 for installation and operation of continuous SO2 emission monitoring equipment is subject to the provisions of paragraph (1).

 (c)  Allentown, Bethlehem, Easton; Reading; Upper Beaver Valley; and Johnstown air basins. Combustion units in these subject air basins must conform with the following:

   (1)  General provision. A person may not permit the emission into the outdoor atmosphere of sulfur oxides, expressed as SO2, from a combustion unit in excess of the rate of 3 pounds per million Btu of heat input over a 1-hour period, except as provided in paragraph (4).

   (2)  Commercial fuel oil.

     (i)   Except as specified in subparagraphs (ii) and (iii), a person may not offer for sale, deliver for use, exchange in trade or permit the use of commercial fuel oil in the subject air basins if the commercial fuel oil contains sulfur in excess of the applicable maximum allowable sulfur content set forth in the following tables:

Grades Commercial Fuel Oil
Maximum Allowable % Sulfur by
Weight through June 30, 2016
No. 2 and Lighter (viscosity less than or equal to 5.82cSt) 0.3
No. 4, No. 5, No. 6 and heavier (viscosity greater than 5.82cSt) 2.0

Maximum Allowable Sulfur Content Beginning July 1, 2016,
Expressed as Parts per Million (ppm) by Weight or Percentage by Weight


Grades Commercial Fuel Oil (Consistent with ASTM D396)
No. 2 and lighter oil 500 ppm
(0.05%)
No. 4 oil 2,500 ppm
(0.25%)
No. 5, No. 6 and heavier oil 5,000 ppm
(0.5%)

     (ii)   Commercial fuel oil that was stored in this Commonwealth by the ultimate consumer prior to July 1, 2016, which met the applicable maximum allowable sulfur content for commercial fuel oil through June 30, 2016, in subparagraph (i) at the time it was stored, may be used by the ultimate consumer in this Commonwealth on and after July 1, 2016.

     (iii)   Beginning July 1, 2016, the Department may temporarily suspend or increase the applicable maximum allowable sulfur content for a commercial fuel oil set forth in subparagraph (i) if the following occur:

       (A)   The Department receives a written request at the address specified in subsection (h) for a suspension or increase on the basis that compliant commercial fuel oil is not reasonably available in a subject air basin. The request must include the following:

         (I)   The subject air basin for which the suspension or increase is requested.

         (II)   The reason compliant commercial fuel oil is not reasonably available.

         (III)   The duration of time for which the suspension or increase is requested and the justification for the requested duration.

       (B)   The Department determines that an insufficient quantity of compliant commercial fuel oil is reasonably available in the air basin and that the circumstances leading to the insufficiency are due to events that could not have been reasonably foreseen or prevented and are not due to lack of prudent planning on the part of the transferor of the commercial fuel oil into or within the air basin.

       (C)   The Department approves the request, in writing, prior to the transferor distributing the noncompliant commercial fuel oil into or within the air basin.

     (iv)   The Department will limit a suspension or increase in the applicable maximum allowable sulfur content granted under subparagraph (iii) to the shortest duration in which adequate supplies of compliant commercial fuel oil can be made reasonably available, but in no case longer than 60 days from the date the Department grants the suspension or increase.

   (3)  Equivalency provision. Paragraph (2) does not apply to a person who uses equipment or a process, or to the owner or operator of an installation where equipment or a process is used, to reduce the sulfur emissions from the burning of a fuel with a higher sulfur content than that specified in paragraph (2). The emissions may not exceed those which would result from the use of commercial fuel oil that meets the applicable maximum allowable sulfur content specified in paragraph (2).

   (4)  Solid fossil fuel fired combustion units. Solid fuel fired combustion units shall conform with the following:

     (i)   This paragraph applies to all solid fossil fuel fired combustion units with a rated capacity greater than or equal to 250 million Btus of heat input per hour and to any solid fossil fuel fired combustion unit upon petition to and acceptance by the Department.

     (ii)   The owner of a solid fossil fuel fired combustion unit with a rated capacity of less than 250 million Btu heat input per hour may petition the Department for application of the limitations in this paragraph in lieu of the limitations in paragraph (1). Upon demonstration of installation of continuous monitoring equipment which complies with Chapter 139 the Department will grant such petition.

     (iii)   No person may permit the emission into the outdoor atmosphere of sulfur oxides, expressed as SO2, from any combustion unit in excess of the rates set forth in the following table:

Allowable Pounds SO2 per
106 Btu Heat Input
Thirty-day running average not to be exceeded at any time 2.8
Daily average not to be exceeded more than 2 days in any running 30-day period 3.0
Daily average maximum not to be exceeded at any time 3.6

     (iv)   A combustion unit not meeting the requirements of §  123.25 for installation and operation of continuous SO2 emission monitoring equipment is subject to the provisions of paragraph (1).

 (d)  Allegheny County; Lower Beaver Valley; and Monongahela Valley air basins. Combustion units in these subject air basins must conform with the following:

   (1)  General provision. A person may not permit the emission into the outdoor atmosphere of sulfur oxides, expressed as SO2, from a combustion unit in excess of one or more of the following:

     (i)   The rate of 1 pound per million Btu of heat input, when the heat input to the combustion unit in millions of Btus per hour is greater than 2.5 but less than 50.

     (ii)   The rate determined by the following formula: A = 1.7E-0.14, where: A = Allowable emissions in pounds per million Btu of heat input, and E = Heat input to the combustion unit in millions of Btus per hours when E is equal to or greater than 50 but less than 2,000.

     (iii)   The rate of 0.6 pounds per million Btu of heat input when the heat input to the combustion unit in millions of Btus per hour is equal to or greater than 2,000.

   (2)  Commercial fuel oil.

     (i)   Except as specified in subparagraphs (ii) and (iii), a person may not offer for sale, deliver for use, exchange in trade or permit the use of commercial fuel oil in the subject air basins on or after July 1, 2016, if the commercial fuel oil contains sulfur in excess of the applicable maximum allowable sulfur content set forth in the following table:

Maximum Allowable Sulfur Content Beginning July 1, 2016,
Expressed as Parts per Million (ppm) by Weight or Percentage by Weight


Grades Commercial Fuel Oil (Consistent with ASTM D396)
No. 2 and lighter oil 500 ppm
(0.05%)
No. 4 oil 2,500 ppm
(0.25%)
No. 5, No. 6 and heavier oil 5,000 ppm
(0.5%)

     (ii)   Commercial fuel oil that was stored in this Commonwealth by the ultimate consumer prior to July 1, 2016, which met the applicable maximum allowable sulfur content at the time it was stored, may be used by the ultimate consumer in this Commonwealth on and after July 1, 2016.

     (iii)   Beginning July 1, 2016, the Department may temporarily suspend or increase the applicable maximum allowable sulfur content for a commercial fuel oil set forth in subparagraph (i) if the following occur:

       (A)   The Department receives a written request at the address specified in subsection (h) for a suspension or increase on the basis that compliant commercial fuel oil is not reasonably available in a subject air basin. The request must include the following:

         (I)   The subject air basin for which the suspension or increase is requested.

         (II)   The reason compliant commercial fuel oil is not reasonably available.

         (III)   The duration of time for which the suspension or increase is requested and the justification for the requested duration.

       (B)   The Department determines that an insufficient quantity of compliant commercial fuel oil is reasonably available in the air basin and that the circumstances leading to the insufficiency are due to events that could not have been reasonably foreseen or prevented and are not due to lack of prudent planning on the part of the transferor of the commercial fuel oil into or within the air basin.

       (C)   The Department approves the request, in writing, prior to the transferor distributing the noncompliant commercial fuel oil into or within the air basin.

     (iv)   The Department will limit a suspension or increase in the applicable maximum allowable sulfur content granted under subparagraph (iii) to the shortest duration in which adequate supplies of compliant commercial fuel oil can be made reasonably available, but in no case longer than 60 days from the date the Department grants the suspension or increase.

   (3)  Equivalency provision. Paragraph (2) does not apply to a person who uses equipment or a process, or to the owner or operator of an installation where equipment or a process is used, to reduce the sulfur emissions from the burning of a fuel with a higher sulfur content than that specified in paragraph (2). The emissions may not exceed those which would result from the use of commercial fuel oil that meets the applicable maximum allowable sulfur content specified in paragraph (2).

 (e)  Southeast Pennsylvania air basin. Combustion units in the Southeast Pennsylvania air basin must conform with the following:

   (1)  General provision. A person may not permit the emission into the outdoor atmosphere of sulfur oxides, expressed as SO2, from a combustion unit except as provided in paragraph (3) or (5), in excess of the applicable rate in pounds per million Btu of heat input specified in the following table:

Rated Capacity of Units in 106 Btus per hour Inner Zone Outer Zone
Less than 250 1.0 1.2
Greater than or equal to 250 0.6 1.2

   (2)  Commercial fuel oil.

     (i)   Except as specified in subparagraphs (ii) and (iii), a person may not offer for sale, deliver for use, exchange in trade or permit the use of commercial fuel oil in a combustion unit in the Southeast Pennsylvania air basin if the commercial fuel oil contains sulfur in excess of the applicable maximum allowable sulfur content set forth in the following tables:

Maximum Allowable % Sulfur by
Weight through June 30, 2016
Grades of Commercial Fuel Oil Inner Zone Outer Zone
No. 2 and lighter (viscosity less than or equal to 5.82cSt) 0.2 0.3
No. 4, No. 5, No. 6 and Heavier (viscosity greater than 5.82cSt) 0.5 1.0


Maximum Allowable Sulfur Content Beginning July 1, 2016,
Expressed as Parts per Million (ppm) by Weight or Percentage by Weight
Grades Commercial Fuel Oil (Consistent with ASTM D396)
No. 2 and lighter oil 500 ppm (0.05%)
No. 4 oil 2,500 ppm (0.25%)
No. 5, No. 6 and heavier oil 5,000 ppm (0.5%)

     (ii)   Commercial fuel oil that was stored in this Commonwealth by the ultimate consumer prior to July 1, 2016, which met the applicable maximum allowable sulfur content for commercial fuel oil through June 30, 2016, in subparagraph (i) at the time it was stored, may be used by the ultimate consumer in this Commonwealth on and after July 1, 2016.

     (iii)   Beginning July 1, 2016, the Department may temporarily suspend or increase the applicable maximum allowable sulfur content for a commercial fuel oil set forth in subparagraph (i) if the following occur:

       (A)   The Department receives a written request at the address specified in subsection (h) for a suspension or increase on the basis that compliant commercial fuel oil is not reasonably available in the subject air basin. The request must include both of the following:

         (I)   The reason compliant commercial fuel oil is not reasonably available.

         (II)   The duration of time for which the suspension or increase is requested and the justification for the requested duration.

       (B)   The Department determines that an insufficient quantity of compliant commercial fuel oil is reasonably available in the air basin and that the circumstances leading to the insufficiency are due to events that could not have been reasonably foreseen or prevented and are not due to lack of prudent planning on the part of the transferor of the commercial fuel oil into or within the air basin.

       (C)   The Department approves the request, in writing, prior to the transferor distributing the noncompliant commercial fuel oil into or within the air basin.

     (iv)   The Department will limit a suspension or increase in the applicable maximum allowable sulfur content granted under subparagraph (iii) to the shortest duration in which adequate supplies of compliant commercial fuel oil can be made reasonably available, but in no case longer than 60 days from the date the Department grants the suspension or increase.

   (3)  Noncommercial fuels. A person may not permit the emission into the outdoor atmosphere of sulfur oxides, expressed as SO2, from a combustion unit using a noncommercial fuel, in excess of the rate of 0.6 pound per million Btu of heat input in the inner zone or 1.2 pounds per million Btu of heat input in the outer zone.

   (4)  Equivalency provision. Paragraph (2) does not apply to a person who uses equipment or a process, or to the owner or operator of an installation where equipment or a process is used, to reduce the sulfur emissions from the burning of a fuel with a higher sulfur content than that specified in paragraph (2). The emissions may not exceed those which would result from the use of commercial fuel oil that meets the applicable maximum allowable sulfur content specified in paragraph (2).

   (5)  Solid fossil fuel fired combustion units. Solid fossil fuel fired combustion units shall conform with the following:

     (i)   This paragraph applies to all solid fossil fuel fired combustion units with a rated capacity greater than or equal to 250 million Btus of heat input per hour and to any solid fossil fuel fired combustion unit upon petition to and acceptance by the Department.

     (ii)   The owner of any solid fossil fuel fired combustion unit with a rated capacity of less than 250 million Btu heat input per hour may petition the Department for application of the limitations in this paragraph in lieu of the limitations in paragraph (1). Upon demonstration of installation of continuous monitoring equipment which complies with Chapter 139, the Department will grant the petition.

     (iii)   No person may permit the emission into the outdoor atmosphere of sulfur oxides, expressed as SO2, from any combustion unit in excess of the applicable rate in pounds per million Btu of heat input specified in the following table:

Rated Capacity of Unit in
106 Btus per Hour
Less than 250 Greater than or equal to 250
Thirty-day running average not to be exceeded at any time
 Inner Zone 0.75 0.45
 Outer Zone 0.90 0.90
Daily average not to be exceeded more than 2 days in any running 30-day period
 Inner Zone 1.00 0.60
 Outer Zone 1.20 1.20
Daily average maximum not to be exceeded at any time
 Inner Zone 1.20 0.72
 Outer Zone 1.44 1.44

     (iv)   A combustion unit not meeting the requirements of §  123.25 for installation and operation of continuous SO2 emission monitoring equipment is subject to the provisions of paragraph (1).

 (f)  Sampling and testing.

   (1)  For the purpose of determining compliance with the requirements of this section, the actual sulfur content of commercial fuel oil shall be determined by one of the following:

     (i)   In accordance with the sample collection, test methods and procedures specified under §  139.16 (relating to sulfur in fuel oil).

     (ii)   Other methods developed or approved by the Department or the Administrator of the EPA, or both.

   (2)  Beginning July 1, 2016, a refinery owner or operator who produces commercial fuel oil intended for use or used in this Commonwealth is required to sample, test and calculate the actual sulfur content of each batch of the commercial fuel oil as specified in paragraph (1).

   (3)  Beginning July 1, 2016, and prior to offering for sale, delivering for use, exchanging in trade or permitting the use of commercial fuel oil in this Commonwealth, a person other than the ultimate consumer that accepts a shipment of commercial fuel oil from a refinery or other transferor, shall sample, test and calculate the actual sulfur content of the commercial fuel oil in accordance with paragraph (1) if the shipment lacks the record required under subsection (g)(1) that enables the transferee to determine if the sulfur content of the shipment of commercial fuel oil meets the applicable maximum allowable sulfur content.

 (g)  Recordkeeping and reporting.

   (1)  Beginning with the refinery owner or operator who sells or transfers commercial fuel oil into or within this Commonwealth for use in this Commonwealth and ending with the ultimate consumer, each time the physical custody of, or title to, a shipment of commercial fuel oil changes hands on or after July 1, 2016, the transferor shall provide to the transferee an electronic or paper record described in this paragraph. This record must legibly and conspicuously contain the following information:

     (i)   The date of the sale or transfer.

     (ii)   The name and address of the transferor.

     (iii)   The name and address of the transferee.

     (iv)   The volume of commercial fuel oil being sold or transferred.

     (v)   The identification of the sulfur content of the shipment of commercial fuel oil, determined using the sampling and testing methods specified in subsection (f)(1), expressed as one of the following statements:

       (A)   For a shipment of No. 2 and lighter commercial fuel oil, ‘‘The sulfur content of this shipment is 500 ppm or below.’’

       (B)   For a shipment of No. 4 commercial fuel oil, ‘‘The sulfur content of this shipment is 2,500 ppm or below.’’

       (C)   For a shipment of No. 5, No. 6 and heavier commercial fuel oil, ‘‘The sulfur content of this shipment is 5,000 ppm or below.’’

     (vi)   The location of the commercial fuel oil at the time of transfer.

     (vii)   Except for a transfer to a truck carrier, an owner or operator of a retail outlet or an ultimate consumer, the transferor may substitute the information required under subparagraphs (i)—(vi) with the use of a product code if the following are met:

       (A)   The product code includes the information required under subparagraphs (i)—(vi).

       (B)   The product code is standardized throughout the distribution system in which it is used.

       (C)   Each downstream party is given sufficient information to know the full meaning of the product code.

   (2)  The refinery owner or operator shall do both of the following:

     (i)   Maintain, in electronic or paper format, the records developed under subsection (f)(2) to determine the actual sulfur content of each batch of the commercial fuel oil.

     (ii)   Provide electronic or written copies of the records developed under subsection (f)(2) of the actual sulfur content of each batch of the commercial fuel oil to the Department upon request.

   (3)  The terminal owner or operator shall do both of the following:

     (i)   Maintain, in electronic or paper format, the applicable records developed under subsection (f)(3) or (g)(1), or both, to establish the maximum sulfur content of the shipment of commercial fuel oil.

     (ii)   Provide electronic or written copies of the records establishing the maximum sulfur content of the shipment of commercial fuel oil to the Department upon request.

   (4)  A person subject to this section shall do both of the following:

     (i)   Maintain the applicable records required under paragraphs (1)—(3) in electronic or paper format for 2 years unless a longer period is required under §  127.511(b)(2) (relating to monitoring and related recordkeeping and reporting requirements).

     (ii)   Provide an electronic or written copy of the applicable record to the Department upon request.

   (5)  The ultimate consumer shall maintain in electronic or paper format the record containing the information listed in paragraph (1), except in either of the following situations:

     (i)   The transfer or use of the commercial fuel oil occurs at a private residence.

     (ii)   The ultimate consumer is an owner of an apartment or condominium building housing private residents and the transfer or use of the commercial fuel oil occurs for use at the building.

 (h)  Written request. The written request for suspension of or increase in the sulfur content limit on the basis that compliant commercial fuel oil is not reasonably available shall be addressed to the Department of Environmental Protection, Bureau of Air Quality, Chief of the Division of Compliance and Enforcement, P. O. Box 8468, Harrisburg, Pennsylvania 17105-8468.

Authority

   The provisions of this §  123.22 issued under section 5 of the Air Pollution Control Act (35 P. S. §  4005); amended under section 5(a)(1) and (8) of the Air Pollution Control Act (35 P. S. §  4005(a)(1) and (8)).

Source

   The provisions of this §  123.22 adopted September 10, 1971, effective September 11, 1971, 1 Pa.B. 1804; amended March 3, 1972, effective March 20, 1972, 2 Pa.B. 383; amended August 4, 1978, effective October 1, 1978, 8 Pa.B. 2163; amended April 27, 1979, effective August 1, 1979, 9 Pa.B. 1447; corrected May 11, 1979, effective August 1, 1979, 9 Pa.B. 1534; amended November 7, 1980, effective January 1, 1981, 10 Pa.B. 4296; amended August 20, 1982, effective August 21, 1982, 12 Pa.B. 2787; amended February 8, 2013, effective February 9, 2013, 43 Pa.B. 806; corrected April 19, 2013, effective May 9, 1987, 43 Pa.B. 2140. Immediately preceding text appears at serial pages (365513) to (365527).

Notes of Decisions

   Impossibility

   There is no constitutional prohibition against imposition of civil penalties for failure to comply with technologically impossible standards, since the use of fines to spark technological development is reasonably related to the goal of reducing pollution. Department of Environmental Resources v. Pennsylvania Power Co., 416 A.2d 995 (Pa. 1980).

   Impossibility of performance is a defense in a contempt proceeding where an order of court ordering a power company to comply with the SO2 regulations was impossible of performance and where, under the present state of technology, the power company’s proposed use of higher smokestacks to control SO2 emissions was as close as the company could come to compliance with the regulations. Department of Environmental Resources v. Pennsylvania Power Co., 316 A.2d 96 (Pa. Cmwlth. 1974).

Cross References

   This section cited in 25 Pa. Code §  121.1 (relating to definitions); 25 Pa. Code §  123.25 (relating to monitoring requirements); 25 Pa. Code §  127.14 (relating to exemptions); 25 Pa. Code §  127.449 (relating to de minimis emission increases); and 25 Pa. Code §  139.16 (relating to sulfur in fuel oil).

§ 123.23. Byproduct coke oven gas.

 (a)  No person may permit the emission of byproduct coke oven gas into the outdoor atmosphere unless the gas is first burned.

 (b)  No person may permit the flaring or combustion of a coke oven byproduct gas which contains sulfur compounds, expressed as equivalent hydrogen sulfide, in concentrations greater than 50 grains per 100 dry standard cubic feet. The sulfur compounds, expressed as equivalent hydrogen sulfide, emitted into the outdoor atmosphere from any tail gas sulfur recovery equipment utilized in a coke oven gas desulfurization system approved by the Department shall be included in the determination of these concentrations.

 (c)  Subsections (a) and (b) do not apply to emissions of coke oven gas from:

   (1)  An oven which is dampered off:

     (i)   Prior to and during the pushing operation of the oven.

     (ii)   Because of some malfunction associated with the oven.

   (2)  Unavoidable oven leakage occurring during the coking cycle.

 (d)  Sections 129.12 and 129.13 (relating to sulfuric acid plants; and sulfur recovery plants) may not be applicable to processes operated in conjunction with the desulfurization of byproduct coke oven gas, provided that the standards in this section have been complied with.

Source

   The provisions of this §  123.23 adopted September 10, 1971, effective September 11, 1971, 1 Pa.B. 1804; amended March 3, 1972, effective March 20, 1972, 2 Pa.B. 383; amended October 25, 1974, effective November 11, 1974, 4 Pa.B. 2283; amended April 27, 1979, effective August 1, 1979, 9 Pa.B. 1534. Immediately preceding text appears at serial page (38907).

Notes of Decisions

   There is no violation of procedural due process where an order to make certain changes in coke oven operations does not place new or increased legal duties on the operator but only redefines and mitigates what had been an immediate, current legal duty under the regulations and a compliance schedule is specified and no variance request is made. Commonwealth v. Crucible Inc., 65 Pa. D. & C.2d 151 (1973).

§ 123.24. Primary zinc smelters.

 (a)  No person may permit the emission into the outdoor atmosphere of sulfur oxides from any zinc roasting operation in such a manner that the concentration of sulfur oxides, expressed as SO2, in the effluent gas exceeds 500 parts per million by volume, dry basis, calculated as a 2-hour moving average.

 (b)  No person may permit the emission into the outdoor atmosphere of sulfur oxides from any zinc sintering operation in excess of the rate calculated by the following formula:

 Y = 0.054X,

 Where:

 X = Calcine feed rate to the sinter plant (lbs/hr); and

 Y = Allowable sulfur oxide emissions (lbs/hr).

Source

   The provisions of this §  123.24 adopted July 25, 1975, effective August 11, 1975, 5 Pa.B. 1916.

§ 123.25. Monitoring requirements.

 (a)  This section applies to the following:

   (1)  Combustion units specified in §  123.22(a)(4), (b)(4), (c)(4) or (e)(5) (relating to combustion units).

   (2)  Fossil fuel—fired steam generators of greater than 250 million Btus per hour of heat input which has installed sulfur dioxide pollutant control equipment.

   (3)  Sulfuric acid plants of greater than 300 tons per day production capacity, the production being expressed as 100% acid.

 (b)  A source subject to this section shall install, operate and maintain continuous SO2 monitoring systems in compliance with Chapter 139 Subchapter C (relating to requirements for continuous in-stack monitoring for stationary sources). Results of emission monitoring shall be submitted to the Department on a regular basis in compliance with Chapter 139 Subchapter C.

 (c)  Continuous SO2 monitoring systems installed under this section shall meet the minimum data availability requirements in Chapter 139 Subchapter C.

 (d)  The following are alternative monitoring systems:

   (1)  The Department will allow sources specified in subsection (a)(1) to utilize sulfur-in-fuel sampling programs in lieu of the requirements of subsection (b). These programs shall meet the requirements of Chapter 139 Subchapter C.

   (2)  The Department may exempt a source from the requirements of subsection (b) if the Department determines that the installation of a continuous emission monitoring system would not provide accurate determination of emissions or that installation of a continuous emission monitoring system cannot be implemented by a source due to physical plant limitations or to extreme economic reasons. The Department will require an exempted source to fulfill alternative emission monitoring and reporting requirements.

 (e)  The Department may use the data from the SO2 monitoring devices or from the alternative monitoring systems required by this section to enforce the emission limitations for SO2 defined in this article.

 (f)  Compliance with this section shall be obtained no later than 18 months after the effective date of the listing of any source identified in subsection (a). The Department may grant orders providing reasonable extension of time for sources that have made good faith efforts to install, operate and maintain continuous monitoring devices, but that have been unable to complete the operations within the time period provided.

 (g)  The Department may use the data from the SO2 monitoring systems or from the alternative monitoring systems required by this section to determine compliance with the applicable emission limitations for SO2 established in this article.

Authority

   The provisions of this §  123.25 issued under the Air Pollution Control Act (35 P. S. § §  4001—4015).

Source

   The provisions of this §  123.25 adopted April 27, 1979, effective August 1, 1979, 9 Pa.B. 1447; amended April 27, 1979, effective August 1, 1979, 9 Pa.B. 1534; amended June 19, 1981, effective June 20, 1981, 11 Pa.B. 2132; amended October 26, 1990, effective October 27, 1990, 20 Pa.B. 5416. Immediately preceding text appears at serial pages (136379) to (136380).

Cross References

   This section cited in 25 Pa. Code §  123.22 (relating to combustion units); and 25 Pa. Code §  139.104 (relating to sulfur dioxide and nitrogen oxides monitoring requirements for combustion sources).

ODOR EMISSIONS


§ 123.31. Limitations.

 (a)  Limitations are as follows:

   (1)  If control of malodorous air contaminants is required under subsection (b), emissions shall be incinerated at a minimum of 1200°F for at least 0.3 second prior to their emission into the outdoor atmosphere.

   (2)  Techniques other than incineration may be used to control malodorous air contaminants if such techniques are equivalent to or better than the required incineration in terms of control of the odor emissions and are approved in writing by the Department.

 (b)  A person may not permit the emission into the outdoor atmosphere of any malodorous air contaminants from any source, in such a manner that the malodors are detectable outside the property of the person on whose land the source is being operated.

 (c)  The prohibition in subsection (b) does not apply to odor emissions arising from the production of agricultural commodities in their unmanufactured state on the premises of the farm operation.

Source

   The provisions of this §  123.31 adopted September 10, 1971, effective September 11, 1971, 1 Pa.B. 1804; amended March 3, 1972, effective March 20, 1972, 2 Pa.B. 383; amended August 12, 1977, effective August 29, 1977, 7 Pa.B. 2251; amended August 12, 1983, effective August 13, 1983, 13 Pa.B. 2478. Immediately preceding text appears at serial page (75541).

Notes of Decisions

   Compliance

   The Department of Environmental Resources was required to deny an application for reactivation of beehive coke ovens, regardless of economic consequences, when the application did not provide any information which would show that the ovens would meet the limitations applicable to fugitive emissions and constitutional rights were not violated even though there was no known method to operate beehive coke ovens in compliance with this title. Rochez Brothers, Inc. v. Department of Environmental Resources, 334 A.2d 790 (Pa. Cmwlth. 1975).

   Review

   On appeal from the Department of Environmental Resources’ refusal to grant an applicant permission to reactivate certain coke ovens, where the appellant did not show that the oven would meet the limitations in this title, but showed only the ‘‘dire need’’ for the coke to be produced, the scope of review was limited to whether constitutional rights were violated, an error of law committed or any necessary finding of fact not supported by the evidence. Rochez Brothers, Inc. v. Department of Environmental Resources, 334 A.2d. 790 (Pa. Cmwlth. 1975).

Cross References

   This section cited in 25 Pa. Code §  271.902 (relating to permits and direct enforceability).

VISIBLE EMISSIONS


§ 123.41. Limitations.

 A person may not permit the emission into the outdoor atmosphere of visible air contaminants in such a manner that the opacity of the emission is either of the following:

   (1)  Equal to or greater than 20% for a period or periods aggregating more than 3 minutes in any 1 hour.

   (2)  Equal to or greater than 60% at any time.

Source

   The provisions of this §  123.41 adopted September 10, 1971, effective September 11, 1971, 1 Pa.B. 1804; amended March 3, 1972, effective March 20, 1972, 2 Pa.B. 383.

Notes of Decisions

   Denial of Application

   On appeal from the Department’s refusal to grant applicant permission to reactivate certain coke ovens, where the appellant does not show that the oven would meet the limitations in this title, but shows only the ‘‘dire need’’ for the coke to be produced, the scope of review is limited to whether constitutional rights were violated, an error of law committed or any necessary finding of fact not supported by the evidence. Rochez Brothers, Inc. v. Department of Environmental Resources, 334 A.2d 790 (Pa. Cmwlth. 1975).

   The Department is required to deny an application for reactivation of beehive coke ovens, regardless of economic consequences, when the application does not provide any information which would show that the ovens would meet the limitations applicable to fugitive emissions, and constitutional rights are not violated even though there is no known method to operate beehive coke ovens in compliance with the regulations. Rochez Brothers, Inc. v. Department of Environmental Resources, 334 A.2d 790 (Pa. Cmwlth. 1975).

   Due Process

   There is no violation of procedural due process where an order to make certain changes in coke oven operations does not place new or increased legal duties on the operator but only redefines and mitigates what had been an immediate, current legal duty under the regulations and a compliance schedule is specified and no variance request is made. Commonwealth v. Crucible, Inc., 65 Pa. D. & C.2d 151 (1973).

   Failure to Appeal

   Where the party is aggrieved by the Department order requiring compliance with 25 Pa. Code §  123.41 (relating to limitations), by a certain date, failure to appeal such order bars an attack on the order and the validity of the regulation on which it was predicated, in a subsequent enforcement proceeding brought by the Department. Department of Environmental Resources v. Wheeling-Pittsburgh Steel Corporation, 348 A.2d 765 (Pa. Cmwlth. 1975); affirmed in part remanded in part; 357 A.2d 320 (Pa. 1977); cert. denied 98 S. Ct. 514 (Pa. 1977).

   Validity of Order

   A steel corporation which is granted an extension of time for compliance with the standards relating to particulate matter emissions may not attack the validity of the order or the regulations on which it was predicated in a subsequent enforcement proceeding, and the corporation does not have the right to trial by jury even though it seeks declaratory relief in its answer to the enforcement petition. Department of Environmental Resources v. Wheeling-Pittsburgh Steel Corporation, 348 A.2d 765 (Pa. Cmwlth. 1975).

Cross References

   This section cited in 25 Pa. Code §  121.8 (relating to compliance responsibilities); 25 Pa. Code §  123.42 (relating to exceptions); 25 Pa. Code §  123.45 (relating to alternative opacity limitations); and 25 Pa. Code §  264.345 (relating to operating requirements).

§ 123.42. Exceptions.

 The limitations of §  123.41 (relating to limitations) shall not apply to a visible emission in any of the following instances:

   (1)  When the presence of uncombined water is the only reason for failure of the emission to meet the limitations.

   (2)  When the emission results from the operation of equipment used solely to train and test persons in observing the opacity of visible emissions.

   (3)  When the emission results from sources specified in §  123.1 (a)(1)—(9) (relating to prohibition of certain fugitive emissions).

   (4)  When arising from the production of agricultural commodities in their unmanufactured state on the premises of the farm operation.

Source

   The provisions of this §  123.42 adopted September 10, 1971, effective September 11, 1971, 1 Pa.B. 1804; amended March 3, 1972, effective March 20, 1972, 2 Pa.B. 383; amended August 12, 1977, effective August 29, 1977, 7 Pa.B. 2251. Immediately preceding text appears at serial page (30967).

§ 123.43. Measuring techniques.

 Visible emissions may be measured using either of the following:

   (1)  A device approved by the Department and maintained to provide accurate opacity measurements.

   (2)  Observers, trained and qualified to measure plume opacity with the naked eye or with the aid of devices approved by the Department.

Cross References

   This section cited in 25 Pa. Code §  264.345 (relating to operating requirements).

§ 123.44. Limitations of visible fugitive air contaminants from operation of any coke oven battery.

 (a)  A person may not permit the operation of a coke oven battery in a manner that visible fugitive air contaminants are emitted in excess of the emissions allowed by the following limitations:

   (1)  The following open charging limitation applies to existing batteries listed in §  121.1 (relating to definitions). The following closed charging limitation applies to any existing battery on which a closed charging system is installed:

     (i)   Open charging. At no time may the aggregated times of visible open charging emissions during any four consecutive charges equal more than 75 seconds.

     (ii)   Closed charging. At no time may there be closed charging emissions during more than one charge out of any ten consecutive charges.

   (2)  At no time may door area emissions from any coke oven exceed 40% opacity 15 minutes or longer after the last charge to that oven.

   (3)  At no time may there be any visible door area emissions from more than 10% of the door area of operating coke ovens, excluding the two-door area representing the last oven charged on any battery and any door areas obstructed from view.

   (4)  At no time may there be visible topside emissions from more than 2.0% of the charging port seals on operating coke ovens in any battery, excluding visible emissions from no more than three ovens which may be dampered off.

   (5)  At no time may there be topside emissions from more than 5.0% of the offtake piping on operating coke ovens in any battery, excluding visible emissions from open standpipe caps on no more than three ovens which may be dampered off.

   (6)  At no time may there be topside emissions from any point on the topside other than allowed emissions from charging port seals and offtake piping under paragraphs (4) and (5).

   (7)  At no time may there be visible emissions from the coke oven gas collector main.

 (b)  The following techniques shall be used for measuring and recording visible fugitive air contaminants from a coke oven battery:

   (1)  Observations of open and closed charging emissions shall be made from any point or points on the topside of a coke oven battery from which an observer can obtain an unobstructed view of the charging operation. The observer shall determine and record the total number of seconds that charging emissions are visible during the charging of coal to the coke oven. The observer shall time the visible charging emissions with a stopwatch while observing the charging operation. Simultaneous emissions from more than one emission point shall be timed and recorded as one emission and may not be added individually to the total time. Open charging emissions may not include any emissions observed after all the charging port covers have been firmly seated following the removal of the larry car, such as emissions occurring when a cover is temporarily removed to permit the sweep-in of spilled coal. The total number of seconds of visible emissions observed, clock time for the initiation and completion of the charging operation, battery identification, and oven number for each charge shall be recorded by the observer. In the event that observations of emissions from a charge are interrupted due to events beyond the control of observer, the data from that charge shall be invalidated and the observer shall note on his observation sheet the reason for invalidating the data. The observer shall then resume observation of the next consecutive charge or charges, and continue until he has obtained a set of four charges for comparison with the emission standard. Compliance with subsection (a)(1) shall be determined by summing the seconds of charging emissions observed during each of the four charges.

   (2)  Observations of door area emissions for the purpose of determining compliance with subsection (a)(2) shall be made at a point above the top of the door but below the battery top, or at the top of any local door area emission control hood. The observer shall place himself no less than 25 feet from the face of the door in a location where his view of the door area is unobstructed.

   (3)  Observations of door area emissions for determining compliance with subsection (a)(3) shall be made from a minimum distance of 25 feet from each door. Each door area shall be observed in sequence for only that period necessary to determine whether or not, at the time, there are visible emissions from any point on the door area while the observer walks along the side of the battery. If the observer’s view of a door area is more than momentarily obstructed, for example, by door machinery, pushing machinery, coke guide, luter truck or opaque steam plumes, he shall record the door area obstructed and the nature of the obstruction and continue the observations with the next door area in sequence which is not obstructed. The observer shall continue this procedure along the entire length of the battery for both sides and shall record the battery identification, battery side and oven door identification number of each door area exhibiting visible emissions. Before completing the observation of door area emissions, the observer shall attempt to reobserve the obstructed doors. Compliance with subsection (a)(3) shall be calculated by application of the following formula, which excludes two door areas representing the last oven charged from the numerator and obstructed door areas from the denominator:

Web Only Graphic

   (4)  Observations of visible emissions from a coke oven topside, other than emissions from the topside defined as open or closed charging emissions or pushing emissions, shall be made and recorded during the time an observer walks the topside of a battery from one end to the other, positioning himself near the center line. During the traverse, the observer may stray from near the center line of the battery and walk as close to the offtake piping as is necessary to determine whether an observed emission is emanating from the offtake piping. Each oven shall be observed in sequence. The observer shall record the battery identification, the points of topside emission from each oven, the oven number and whether an oven was dampered off. Compliance with subsection (a)(4) shall be determined by application of the following formula:

Web Only Graphic

Authority

   The provisions of this §  123.44 issued under section 1920-A of The Administrative Code of 1929 (71 P. S. §  510-20); and section 5 of the Air Pollution Control Act (35 P. S. §  4005).

Source

   The provisions of this §  123.44 adopted August 12, 1977, effective December 31, 1977, 7 Pa.B. 2251; corrected November 4, 1977, effective December 31, 1977, 7 Pa.B. 3260; amended August 12, 1983, effective August 13, 1983, 13 Pa.B. 2478; amended December 26, 1997, effective December 27, 1997, 27 Pa.B. 6804. Immediately preceding text appears at serial pages (215785) to (215788).

Cross References

   This section cited in 25 Pa. Code §  123.1 (relating to prohibition of certain fugitive emissions); and 25 Pa. Code §  129.16 (relating to door maintenance, adjustment and replacement practices).

§ 123.45. Alternative opacity limitations.

 (a)  Coverage. Coverage shall comply with the following:

   (1)  This section applies to a source:

     (i)   That is covered under §  123.41 (relating to limitations) and is also covered by an emission limitation in the form of a mass rate or a stack gas concentration or a fuel requirement.

     (ii)   That is not a fugitive air contaminant.

     (iii)   For which the mass rate or concentration can be determined:

       (A)   Using techniques specified in § §  139.11—139.16.

       (B)   By any other method approved by the Department that is consistent with accepted air pollution testing practices and with obtaining accurate results that are representative of the conditions evaluated.

   (2)  Appendix D presents the applicability of this section for various emission limitation formats.

 (b)  Procedure for application. The procedure for application shall comply with the following:

   (1)  The owner or operator of a source may request the Department to determine the opacity of emissions from the source during a demonstration of compliance with the applicable mass rate standard or stack gas concentration standard or fuel requirement. The request must be made in the form of a plan approval application under Chapter 127 Subchapter A (relating to general).

   (2)  The owner or operator shall provide for any test the Department deems necessary for determining compliance with the applicable emission limitation.

   (3)  The owner or operator shall provide sufficient notification to the Department so that the proposed test methods may be reviewed and approved by the Department. No test will be considered by the Department for the purpose of establishing an alternative opacity limitation unless the test methods have been first approved by the Department and a trained and qualified observer is present during the test.

 (c)  Eligibility. A source shall be eligible for an alternative opacity limitation (AOL) if the following conditions are met:

   (1)  The Department finds that the source is in compliance with this article except §  123.41. The Department will specify the method of demonstrating compliance.

   (2)  During the time the determination of compliance and AOL is conducted, the source fails to meet any applicable opacity limitation.

   (3)  The Department finds:

     (i)   That the source has not discontinued measures to minimize opacity of emissions, within the bounds of good engineering and good economic practice.

     (ii)   That the source and associated air pollution control equipment are operated and maintained in a manner to minimize the opacity of emissions, within the bounds of good engineering and good economic practice.

   (4)  The demonstration of compliance and the alternative opacity tests are performed under the conditions established by the Department.

   (5)  The Department determines that the AOL would not create or contribute to a public nuisance nor cause air pollution as defined under the act.

 (d)  Level of the alternative standard. The Department will set the AOL at the opacity levels measured during the performance test, even if the emissions were substantially less than those allowed under the regulations or permit conditions of the Department. The Department will enter the AOL as a condition of the operating permit of the source.

 (e)  Operating conditions. The Department will specify the operating conditions under which the determination of compliance and AOL will be made. The conditions must be based on technical knowledge of the process concerning normal operation and the effects of deviations from normal operations.

 (f)  Timing of test. The Department will specify the day, time of day and time of year for conducting the determination of compliance and AOL where these factors may substantially affect the determination of source opacity. Where the source exhibits high opacity only under certain specified conditions or during certain times, the Department may limit the applicability of the AOL to operation during those conditions or times. These conditions or times must be specified in the permit.

 (g)  Continuous monitoring. Continuous monitoring shall consist of the following:

   (1)  A source that requests an AOL must install, operate and maintain a continuous opacity monitor before the determination of compliance and AOL is made.

   (2)  The Department will use the data from the monitor during the determination of compliance and AOL to set the AOL. After the AOL is entered on the operating permit of the source, the Department will use the data from the monitor to enforce the AOL.

   (3)  The Department may exempt a source from the requirement of paragraph (1) if the Department determines that the monitor would not give representative opacity readings for that source. The Department may require an exempted source to:

     (i)   Use trained and qualified observers to measure the opacity.

     (ii)   Monitor and report operating parameters of the process and of air pollution control equipment.

     (iii)   Perform such activities on a specified schedule maintaining relevant records for inspection by the Department.

 (h)  Granting and quantifying the AOL. Granting and quantifying the AOL include the following:

   (1)  The Department will issue a permit establishing the AOL for the source or will deny the application for plan approval if the Department determines that the source is not eligible for, or entitled to, an AOL.

   (2)  The Department will use the procedure of § §  139.17 and 139.18 (relating to general requirements; and calculation of alternative opacity limitations) to quantify the AOL.

 (i)  Special situations. Special situations include the following:

   (1)  For sources that make several products of varying opacity-producing capabilities, the Department may establish an overall AOL independent of the product. The Department may, however, establish a separate AOL for each product where the Department determines that the opacities from the products differ to such an extent that enforcement of the mass rate standard or stack gas concentration standard or fuel requirement may be hampered with only one AOL.

   (2)  For cases in which several processes vent to a single stack, the Department will set an AOL at the opacity level produced after each process is determined to be in compliance with the appropriate mass rate standard or stack gas concentration standard or fuel requirement.

 (j)  Revocation of AOL. Revocation of AOL shall be as follows:

   (1)  The Department may revoke a source’s AOL if the Department determines that:

     (i)   The source is not in compliance with this article.

     (ii)   The source has discontinued measures to minimize opacity of emissions, within the bounds of good engineering and good economic practice.

     (iii)   The plume opacity of the source creates or contributes to a public nuisance or causes air pollution as defined under the act.

   (2)  If the Department revokes a source’s AOL, the opacity of the source will be regulated by §  123.41. The Department may reinstate a revoked AOL if it determines that the conditions which caused the revocation no longer exist.

 (k)  Maintenance of continuous monitor; reestablishment of AOL. Reestablishment of an AOL shall be as follows:

   (1)  The Department may require the owner or operator of a source with an approved AOL and a continuous opacity monitor to do any or all of the following if a trained observer of the Department determines that the source is violating an AOL:

     (i)   Adjust or replace the continuous opacity monitor.

     (ii)   Retest opacity with monitor and trained and qualified observer.

     (iii)   Perform a test to determine compliance with the appropriate mass rate standard or stack gas concentration standard or fuel requirement.

   (2)  For a source with an AOL established by use of a continuous opacity monitor, the Department may establish a new AOL based on opacity readings by a trained and qualified observer if:

     (i)   The Department determines that the source complies with the applicable mass rate standard or stack gas concentration standard or fuel requirement.

     (ii)   The trained and qualified observer of the Department notifies the source that it does not comply with the existing AOL.

     (iii)   The data from the continuous opacity monitor indicate that the source complies with the existing AOL.

Authority

   The provisions of this §  123.45 issued under the Air Pollution Control Act (35 P. S. § §  4001—4015).

Source

   The provisions of this §  123.45 adopted June 19, 1981, effective June 20, 1981, 11 Pa.B. 2132.

Cross References

   This section cited in 25 Pa. Code §  139.17 (relating to general requirements); and 25 Pa. Code §  139.18 (relating to calculation of alternative opacity limitations).

§ 123.46. Monitoring requirements.

 (a)  The following sources are subject to this section:

   (1)  Fossil fuel-fired steam generators with an annual average capacity factor of greater than 30%, as demonstrated to the Department by the owner or operator, and of greater than 250 million Btu per hour heat input except where:

     (i)   Natural gas is the only fuel burned.

     (ii)   Oil or a mixture of gas and oil are the fuels burned and the source is able to comply with the applicable particulate matter and opacity regulations without utilization of particulate matter collection equipment and the source has not been found, within the 5 years previous to the applicability of this section, through any administrative or judicial proceedings to be in violation of any visible emissions standard.

   (2)  Catalyst regenerators for fluid bed catalytic cracking units at petroleum refineries, if the unit is of greater than 20,000 barrels per day fresh feed capacity.

 (b)  All sources subject to the provisions of this section shall install, operate and maintain continuous opacity monitoring devices in compliance with Chapter 139, Subchapter C (relating to requirements for continuous in-stack monitoring for stationary sources). Results of opacity monitoring shall be submitted to the Department on a regular basis in compliance with the requirements of Chapter 139, Subchapter C.

 (c)  The Department may exempt a source from the requirements of subsection (b) if the Department determines that the installation of a continuous emission monitoring system would not provide accurate determination of emissions or that installation of a continuous emission monitoring system may not be implemented by a source due to physical plant limitations or to extreme economic reasons. The Department will require such an exempted source to fulfill alternative emission monitoring and reporting requirements.

 (d)  The Department may use the data from the monitoring devices or from the alternative monitoring systems required by this section to enforce the visible emission limitations defined in this article.

 (e)  Compliance with this section shall be obtained no later than 18 months after the effective date of the listing of any source identified in subsection (a). The Department may grant orders providing reasonable extension of time for sources that have made good faith efforts to install, operate and maintain continuous monitoring devices but have been unable to complete such operations within the time period provided.

Authority

   The provisions of this §  123.46 issued under the Air Pollution Control Act (35 P. S. § §  4001—4015).

Source

   The provisions of this §  123.46 adopted June 19, 1981, effective June 20, 1981, 11 Pa.B. 2132; corrected June 26, 1981, effective June 20, 1981, 11 Pa.B. 2225.

NITROGEN COMPOUND EMISSIONS


§ 123.51. Monitoring requirements.

 (a)  This section applies to combustion units with a rated heat input of 250 million Btus per hour or greater and with an annual average capacity factor of greater than 30%.

 (b)  Sources subject to this section shall install, operate and maintain continuous nitrogen oxides monitoring systems and other monitoring systems to convert data to required reporting units in compliance with Chapter 139, Subchapter C (relating to requirements for continuous in-stack monitoring for stationary sources).

 (c)  Sources subject to this section shall submit results on a regular schedule and in a format acceptable to the Department and in compliance with Chapter 139, Subchapter C.

 (d)  Continuous nitrogen oxides monitoring systems installed under the requirements of this section shall meet the minimum data availability requirements in Chapter 139, Subchapter C.

 (e)  The Department may exempt a source from the requirements of subsection (b) if the Department determines that the installation of a continuous emission monitoring system would not provide accurate determination of emissions or that installation of a continuous emission monitoring system cannot be implemented by a source due to physical plant limitations or to extreme economic reasons. A source exempted from the requirements of subsection (b) shall satisfy alternative emission monitoring and reporting requirements proposed by the source and approved by the Department which provide oxides emission data that is representative of actual emissions of the source.

 (f)  Sources subject to this section shall comply by October 20, 1993, unless the source becomes subject to the requirements later than October 20, 1990. For sources which become subject to the requirements after October 20, 1990, the source has 36 months from the date the source becomes subject to this section. The Department may issue orders providing a reasonable extension of time for sources that have made good faith efforts to install, operate and maintain continuous monitoring devices, but that have been unable to complete the operations within the time period provided.

Authority

   The provisions of this §  123.51 issued under the Air Pollution Control Act (35 P. S. § §  4001—4015).

Source

   The provisions of this §  123.51 adopted October 19, 1990, effective October 20, 1990, 20 Pa.B. 5291.

Cross References

   This section cited in 25 Pa. Code §  129.91 (relating to control of major sources of NOx and VOCs).

NOx ALLOWANCE REQUIREMENTS


§ 123.101. Purpose.

 Sections 123.102—123.120 and this section establish a NOx budget and a NOx allowance trading program for NOx affected sources for the purpose of achieving the health based ozone ambient air quality standard.

Source

   The provisions of this §  123.101 adopted October 31, 1997, effective November 1, 1997, 27 Pa.B. 5683.

Cross References

   This section cited in 25 Pa. Code §  123.103 (relating to general NOx allowance provisions); 25 Pa. Code §  123.108 (relating to source emissions monitoring requirements); 25 Pa. Code §  123.111 (relating to failure to meet service compliance requirements); 25 Pa. Code §  123.112 (relating to source operating permit provision requirements); 25 Pa. Code §  123.113 (relating to source recordkeeping requirements); 25 Pa. Code §  123.115 (relating to initial NOx allowance NOx allocations); 25 Pa. Code §  123.116 (relating to source opt-in provisions); 25 Pa. Code §  123.117 (relating to new NOx affected source provisions); 25 Pa. Code §  123.118 (relating to emission reduction credit provisions); 25 Pa. Code §  123.120 (relating to audit); 25 Pa. Code §  123.121 (relating to NOx Allowance Program transition); and 25 Pa. Code §  145.43 (relating to compliance supplement pool).

§ 123.102. Source NOx allowance requirements and NOx allowance
control period.

 (a)  The owner or operator or each NOx affected source shall, by December 31 of each calendar year, hold a quantity of NOx allowances meeting the requirements of §  123.110(a) (relating to source compliance requirements) in the source’s current year NATS account that is equal to or greater than the total NOx emitted from the source during that year’s NOx allowance control period.

 (b)  The initial NOx allowance control period begins on May 1, 1999.

Source

   The provisions of this §  123.102 adopted October 31, 1997, effective November 1, 1997, 27 Pa.B. 5683.

Cross References

   This section cited in 25 Pa. Code §  123.101 (relating to purpose); 25 Pa. Code §  123.103 (relating to general NOx allowance provisions); 25 Pa. Code §  123.108 (relating to source emissions monitoring requirements); 25 Pa. Code §  123.111 (relating to failure to meet source compliance requirements); 25 Pa. Code §  123.112 (relating to source operating permit provision requirements); 25 Pa. Code §  123.113 (relating to source recordkeeping requirements); 25 Pa. Code §  123.115 (relating to initial NOx allowance NOx allocations); 25 Pa. Code §  123.116 (relating to source opt-in provisions); 25 Pa. Code §  123.117 (relating to new NOx affected source provisions); 25 Pa. Code §  123.118 (relating to emission reduction credit provisions); 25 Pa. Code §  123.120 (relating to audit); 25 Pa. Code §  123.121 (relating to NOx Allowance Program transition); and 25 Pa. Code §  145.43 (relating to compliance supplement pool).

§ 123.103. General NOx allowance provisions.

 (a)  NOx allowances shall be allocated, transferred or used as whole NOx allowances. To determine the number of whole NOx allowances, the number of NOx allowances shall be rounded down for decimals less than 0.50 and rounded up for decimals of 0.50 or greater.

 (b)  A NOx allowance does not constitute a security or other form of property.

 (c)  Allowances may not be used to meet the requirements of this subchapter prior to the year for which they are allocated.

 (d)  For the purposes of account reconciliation, NOx allowances allocated for the NOx allowance control period shall be deducted first, and remaining allowances if not otherwise designated by the source shall be deducted on a first-in, first-out basis.

 (e)  NOx allowances may only be used to comply with § §  123.101, 123.102, 123.104—123.120 and this section.

Source

   The provisions of this §  123.103 adopted October 31, 1997, effective November 1, 1997, 27 Pa.B. 5683; 25 Pa. Code §  123.121 (relating to NOx Allowance Program transition); and 25 Pa. Code §  145.43 (relating to compliance supplement pool).

Cross References

   This section cited in 25 Pa. Code §  123.101 (relating to purpose); 25 Pa. Code §  123.108 (relating to source emissions monitoring requirements); 25 Pa. Code §  123.111 (relating to failure to meet source compliance requirements); 25 Pa. Code §  123.112 (relating to source operating permit provision requirements); 25 Pa. Code §  123.113 (relating to source recordkeeping requirements); 25 Pa. Code §  123.115 (relating to initial NOx allowance NOx allocations); 25 Pa. Code §  123.116 (relating to source opt-in provisions); 25 Pa. Code §  123.117 (relating to new NOx affected source provisions); 25 Pa. Code §  123.118 (relating to emission reduction credit provisions); 25 Pa. Code §  123.120 (relating to audit); 25 Pa. Code §  123.121 (relating to NOx Allowance Program transition); and 25 Pa. Code §  145.43 (relating to compliance supplement pool).

§ 123.104. Source authorized account representative requirements.

 (a)  The owner or operator of a NOx affected source shall designate for each source account, one authorized account representative and one alternate. Initial designations shall be submitted to the Department by December 1, 1997. An authorized account representative may be replaced or, for a new NOx affected source, designated with the submittal of a new ‘‘Account Certificate of Representation.’’

 (b)  The ‘‘Account Certificate of Representation’’ shall be signed by the authorized account representative for the NOx affected source and contain, at a minimum, the following:

   (1)  Identification of the NOx affected source by plant name, state and fossil fired indirect heat transfer combustion unit number for which the certification of representation is submitted.

   (2)  The name, address, telephone and facsimile number of the authorized account representative and the alternate.

   (3)  A list of owners and operators of the NOx affected source.

   (4)  The verbatim statement, ‘‘I certify that I,


, was selected as the Authorized Account Representative (name) by an agreement binding on the owners and operators of the NOx affected source legally designated as
.’’ (name of facility)

 (c)  The alternate authorized account representative shall have the same authority as the authorized account representative. Correspondence from the NOx budget administrator shall be directed to the authorized account representative.

 (d)  Only an authorized account representative or the designated alternate may request transfers of NOx allowances in a NATS account. The authorized account representative shall be responsible for all transactions and reports submitted to the NATS.

 (e)  Authorized account representative designation or changes become effective upon the logged date of receipt of a complete application by the NOx budget administrator from the Department. The NOx budget administrator will acknowledge receipt and the effective date of the changes by written correspondence to the authorized account representative.

Source

   The provisions of this §  123.104 adopted October 31, 1997, effective November 1, 1997, 27 Pa.B. 5683.

Cross References

   This section cited in 25 Pa. Code §  123.101 (relating to purpose); 25 Pa. Code §  123.103 (relating to general NOx allowance provisions); 25 Pa. Code §  123.108 (relating to source emissions monitoring requirements); 25 Pa. Code §  123.111 (relating to failure to meet source compliance requirements); 25 Pa. Code §  123.112 (relating to source operating permit provision requirements); 25 Pa. Code §  123.113 (relating to source recordkeeping requirements); 25 Pa. Code §  123.115 (relating to initial NOx allowance NOx allocations); 25 Pa. Code §  123.116 (relating to source opt-in provisions); 25 Pa. Code §  123.117 (relating to new NOx affected source provisions); 25 Pa. Code §  123.118 (relating to emission reduction credit provisions); 25 Pa. Code §  123.120 (relating to audit); 25 Pa. Code §  123.121 (relating to NOx Allowance Program transition); and 25 Pa. Code §  145.43 (relating to compliance supplement pool).

§ 123.105. NATS provisions.

 (a)  The NATS account records shall constitute a NOx affected source’s NOx allowance holdings.

 (b)  The transfer, use and deduction of NOx allowances become effective only after entry in the tracking system account records.

 (c)  Any person may hold an account in the NATS.

Source

   The provisions of this §  123.105 adopted October 31, 1997, effective November 1, 1997, 27 Pa.B. 5683.

Cross References

   This section cited in 25 Pa. Code §  123.101 (relating to purpose); 25 Pa. Code §  123.103 (relating to general NOx allowance provisions); 25 Pa. Code §  123.108 (relating to source emissions monitoring requirements); 25 Pa. Code §  123.111 (relating to failure to meet source compliance requirements); 25 Pa. Code §  123.112 (relating to source operating permit provision requirements); 25 Pa. Code §  123.113 (relating to source recordkeeping requirements); 25 Pa. Code §  123.115 (relating to initial NOx allowance NOx allocations); 25 Pa. Code §  123.116 (relating to source opt-in provisions); 25 Pa. Code §  123.117 (relating to new NOx affected source provisions); 25 Pa. Code §  123.118 (relating to emission reduction credit provisions); 25 Pa. Code §  123.120 (relating to audit); 25 Pa. Code §  123.121 (relating to NOx Allowance Program transition); and 25 Pa. Code §  145.43 (relating to compliance supplement pool).

§ 123.106. NOx allowance transfer protocol.

 (a)  NOx allowances may be transferred at any time between January 31 and December 31 in accordance with §  123.107 (relating to NOx allowance transfer procedures).

 (b)  NOx allowances shall be held by the originating account at the time of the transfer request.

 (c)  A transfer request shall be filed jointly with the NOx budget administrator and the Department by the person named as the authorized account representative for the originating account.

 (d)  The transfer is effective as of the date the NOx budget administrator posts the transfer of the allowances on the NATS.

Source

   The provisions of this §  123.106 adopted October 31, 1997, effective November 1, 1997, 27 Pa.B. 5683.

Cross References

   This section cited in 25 Pa. Code §  123.101 (relating to purpose); 25 Pa. Code §  123.103 (relating to general NOx allowance provisions); 25 Pa. Code §  123.108 (relating to source emissions monitoring requirements); 25 Pa. Code §  123.111 (relating to failure to meet source compliance requirements); 25 Pa. Code §  123.112 (relating to source operating permit provision requirements); 25 Pa. Code §  123.113 (relating to source recordkeeping requirements); 25 Pa. Code §  123.115 (relating to initial NOx allowance NOx allocations); 25 Pa. Code §  123.116 (relating to source opt-in provisions); 25 Pa. Code §  123.117 (relating to new NOx affected source provisions); 25 Pa. Code §  123.118 (relating to emission reduction credit provisions); 25 Pa. Code §  123.120 (relating to audit); 25 Pa. Code §  123.121 (relating to NOx Allowance Program transition); and 25 Pa. Code §  145.43 (relating to compliance supplement pool).

§ 123.107. NOx allowance transfer procedures.

 NOx allowances may be transferred under the following conditions:

   (1)  The transfer request shall be documented on a form, or electronic media, approved by the Department. The following information, at a minimum, shall be provided:

     (i)   The account number identifying both the originating account and the acquiring account.

     (ii)   The name and address associated with the owners of the originating account and the acquiring account.

     (iii)   The identification of the serial numbers for each NOx allowance being transferred.

   (2)  The transfer request shall be authorized and certified by the authorized account representative for the originating account. To be considered correctly submitted, the request for transfer shall include the following statement of certification:

  ‘‘I am authorized to make this submission on behalf of the owners and operators of the NOx affected source and I hereby certify under the penalty provisions contained in the Air Pollution Control Act, that I have personally examined the foregoing and am familiar with the information contained in this document, and all attachments, and that based on my inquiry of those individuals immediately responsible for obtaining the information, I believe the information is true, accurate and complete. I am aware that there are significant penalties for submitting false information, including possible fines and imprisonment.’’

 The authorized account representative for the originating account shall provide a copy of the transfer request to each owner or operator of the NOx affected source.

Source

   The provisions of this §  123.107 adopted October 31, 1997, effective November 1, 1997, 27 Pa.B. 5683.

Cross References

   This section cited in 25 Pa. Code §  123.101 (relating to purpose); 25 Pa. Code §  123.103 (relating to general NOx allowance provisions); 25 Pa. Code §  123.106 (relating to NOx allowance transfer protocol); 25 Pa. Code §  123.108 (relating to source emissions monitoring requirements); 25 Pa. Code §  123.110 (relating to source compliance requirements); 25 Pa. Code §  123.111 (relating to failure to meet source compliance requirements); 25 Pa. Code §  123.112 (relating to source operating permit provision requirements); 25 Pa. Code §  123.113 (relating to source recordkeeping requirements); 25 Pa. Code §  123.115 (relating to initial NOx allowance NOx allocations); 25 Pa. Code §  123.116 (relating to source opt-in provisions); 25 Pa. Code §  123.117 (relating to new NOx affected source provisions); 25 Pa. Code §  123.118 (relating to emission reduction credit provisions); 25 Pa. Code §  123.120 (relating to audit); 25 Pa. Code §  123.121 (relating to NOx Allowance Program transition); and 25 Pa. Code §  145.43 (relating to compliance supplement pool).

§ 123.108. Source emissions monitoring requirements.

 The owner and operator of each NOx affected source shall comply with the following requirements:

   (1)  NOx emissions from each NOx affected source shall be monitored as specified by this section and in accordance with the procedures contained in the document titled, ‘‘Guidance for Implementation of Emission Monitoring Requirements for the NOx Budget Program.’’

   (2)  The owner or operator of each NOx affected source shall submit to the Department and the NOx budget administrator a monitoring plan in accordance with the procedures outlined in the document titled, ‘‘Guidance for Implementation of Emission Monitoring Requirements for the NOx Budget Program.’’

   (3)  New and existing unit emission monitoring systems, as required and specified by this section, shall be installed and be operational and shall have met all of the certification testing requirements in accordance with the procedures and deadlines specified in the document titled, ‘‘Guidance for Implementation of Emission Monitoring Requirements for the NOx Budget Program’’ in a manner consistent with Chapter 139 (relating to sampling and testing).

   (4)  Monitoring systems are subject to initial performance testing and periodic calibration, accuracy testing and quality assurance/quality control testing as specified in the document titled ‘‘Guidance for Implementation of Emission Monitoring Requirements for the NOx Budget Program.’’ Notwithstanding this provision, Non-Part 75 Sources which have Department approved NOx CEMS reporting in accordance with §  139.101 (relating to gen-eral requirements) in units of pounds of NOx per hour shall complete the periodic self-audits listed in the quality assurance section of §  139.102(3) (relating to references) at least annually and no sooner than 6 months following the previous periodic self-audit. If practicable, the audit shall be conducted between April 1 and May 31.

   (5)  During a period when valid data is not being recorded by devices approved for use to demonstrate compliance with this subchapter, missing or invalid data shall be replaced with representative default data in accordance with 40 CFR Part 75 (relating to continuous emission monitoring) and the document titled, ‘‘Guidance for Implementation of Emission Monitoring Requirements for the NOx Budget Program.’’ Notwithstanding this provision, Non-Part 75 Sources which have Department approved NOx CEMS reporting in accordance with §  139.101 in units of pounds of NOx per hour shall report this data to the NETS and shall continue report submissions as required under Chapter 139 to the Department.

   (6)  Sources subject to 40 CFR Part 75 shall demonstrate compliance with this section with a certified Part 75 monitoring system.

     (i)   If the source has a flow monitor certified under Part 75, NOx in pounds per hour shall be determined using the Part 75 NOx CEMS and the flow monitor. The NOx emission rate in pounds per million Btu shall be determined using the procedure in 40 CFR Part 75 Appendix F, Section 3 (relating to procedures for NOx emission rate). The hourly heat input shall be determined by using the procedures in 40 CFR Part 75 Appendix F, Section 5 (relating to procedures for heat input). NOx in pounds per hour shall be determined by multiplying the NOx per million Btu by the Btus per hour.

     (ii)   If a Part 75 source does not have a certified flow monitor, but does have a certified NOx CEMS, NOx emissions in pounds per hour emissions shall be determined by using the NOx CEMS to determine the NOx emission rate in pounds per million Btu and the heat input shall be determined by using the procedures in 40 CFR Part 75 Appendix D (relating to optional SO2 emissions data protocol for gas-fired and oil-fired units). NOx in pounds per hour shall be determined by multiplying the NOx per million Btu and Btus per hour.

     (iii)   If the owner or operator of a source uses the procedures in 40 CFR Part 75, Appendix E (relating to optional NOx emissions estimation protocol for gas-fired peaking units and oil-fired peaking units) to determine the NOx emission rate, NOx emissions in pounds per hour shall be determined by multiplying the NOx emission rate determined by using the Appendix E procedures times the heat input determined using the procedures in 40 CFR Part 75, Appendix D.

     (iv)   If the owner or operator of a source uses the procedures in 40 CFR Part 75, Subpart E (relating to alternative monitoring systems) to determine NOx emission rate, NOx emissions in pounds per hour shall be determined using the alternative monitoring method approved under 40 CFR Part 75 Subpart E and the procedures contained in the document titled, ‘‘Guidance for Implementation of Emission Monitoring Requirements for the NOx Budget Program.’’

     (v)   If the source emits to common or multiple stacks, or both, the source shall monitor emissions according to the procedures contained in the document titled, ‘‘Guidance for Implementation of Emission Monitoring Requirements for the NOx Budget Program.’’

   (7)  Sources not subject to 40 CFR Part 75 and not meeting the requirements of paragraph (11) shall meet the monitoring requirements of this section by:

     (i)   Preparing and obtaining approval of a monitoring plan as specified in the document titled, ‘‘Guidance for Implementation of Emission Monitoring Requirements for the NOx Budget Program.’’

     (ii)   Determining NOx emission rate and heat input using a methodology specified in paragraphs (8) and (9) respectively or determining NOx concentration and flow using a methodology specified in paragraphs (8) and (9) respectively.

     (iii)   Calculating NOx emissions in pounds per hour using the procedure described in paragraph (10).

   (8)  The owner or operator of a NOx affected source which is not subject to 40 CFR Part 75, may implement an alternative emission rate monitoring method. The NOx emission rate in pounds per million Btu or NOx concentration in ppm shall be determined using one of the following methods:

     (i)   The owner or operator of a NOx affected source that has a maximum rated heat input capacity of 250 MMBtu/hr or greater which is not a peaking unit as defined in 40 CFR 72.2 (relating to definitions), which combusts any solid fuel or is required to or has installed a NOx continuous emissions monitoring system (NOx CEMS) for the purposes of meeting either the requirements of 40 CFR Part 60 (relating to standards of performance for new stationary sources) or another Department or Federal requirement, shall use that NOx CEMS to meet the requirements of this section. If the owner or operator of the unit monitors flow according to paragraph (9), the owner or operator may use the NOx CEMS to measure NOx in ppm, otherwise the NOx CEMS shall be used to measure the emission rate in lb/MMBtu. The owner or operator shall install, certify, operate and maintain this monitor in accordance with the ‘‘Guidance for Implementation of Emission Monitoring Requirements for the NOx Budget Program.’’ When a NOx CEMS cannot be used to report data for this program because it does not meet the requirements of the ‘‘Guidance for Implementation of Emission Monitoring Requirements for the NOx Budget Program,’’ missing data shall be substituted using the procedures in that document. In addition, the NOx CEMS shall meet the initial certification requirements contained in the ‘‘Guidance for Implementation of Emission Monitoring Requirements for the NOx Budget Program.’’

     (ii)   The owner or operator of a source that is not required to have a NOx CEMS, may request approval from the Department to use any of the following appropriate methodologies to determine the NOx emission rate:

       (A)   Boilers or turbines may use the procedures contained in 40 CFR Part 75 Appendix E to measure NOx emission rate in pounds/MMBtu, consistent with the ‘‘Guidance for Implementation of Emission Monitoring Requirements for the NOx Budget Program.’’

       (B)   Owners and operators of combustion turbines that are subject to this section and § §  123.101—123.107 and 123.109—123.120 may also meet the monitoring requirements of this section and § §  123.101—123.107 and 123.109—123.120 by using default emission factors to determine NOx emissions in pounds per hour as follows:

         (I)   For gas-fired turbines, the default emission factor is 0.7 pounds NOx per MMBtu.

         (II)   For oil-fired turbines, the default factor is 1.2 pounds NOx per MMBtu.

         (III)   Owners and operators of gas turbines or oil-fired turbines may perform testing, consistent with ‘‘Guidance for Implementation of Emission Monitoring Requirements for the NOx Budget Program,’’ to determine unit specific maximum potential NOx emission rates.

       (C)   Owners and operators of boilers that are subject to this section and § §  123.101—123.107 and 123.109—123.120 may meet the monitoring requirements of this section and § §  123.101—123.107 and 123.109—123.120 by using a default emission factor of 2.0 pounds per MMBtu if they burn oil and 1.5 lb/MMBtu if they burn natural gas to determine NOx emissions in pounds per hour, or may perform testing consistent with the ‘‘Guidance for Implementation of Emission Monitoring Requirements for the NOx Budget Program,’’ to determine a unit specific maximum potential emission rate.

   (9)  The owner or operator of a source which is not subject to 40 CFR Part 75, and not meeting the requirements of paragraph (11), shall determine heat input in MMBtu or flow in standard cubic feet per hour using one of the following methods:

     (i)   The owner or operator of a source may install and operate a flow monitor according to 40 CFR Part 75.

       (A)   The owner or operator may either use the flow CEMS to monitor stack flow in standard cubic feet per hour and a NOx CEMS to monitor NOx in ppm.

       (B)   In the alternative, the owner or operator may use the flow CEMS and a diluent CEMS to determine heat input in MMBtu and a NOx CEMS to monitor NOx in lbs/MMBtu.

     (ii)   The owner or operator of a source that does not have a flow CEMS may request approval from the Department to use any of the following methodologies to determine their heat input rate:

       (A)   The owner or operator of a source may determine heat input using a flow monitor and a diluent monitor meeting 40 CFR Part 75 and the procedures in 40 CFR Part 75, Appendix F Section 5.

       (B)   The owner or operator of a source that combusts only oil or natural gas may determine heat input using a fuel flow monitor meeting 40 CFR Part 75 Appendix D and the procedures of 40 CFR Part 75, Appendix F Section 5.

       (C)   The owner or operator of a source that combusts only oil or natural gas which uses a unit specific or generic default NOx emission rate, may determine heat input by measuring the fuel usage for a specified frequency of longer than an hour. This fuel usage shall then be reported on an hourly basis by apportioning the fuel based on electrical load in accordance with the following formula:

Web Only Graphic

       (D)   The owner or operator of a source that combusts any fuel other than oil or natural gas, may request permission from the Department to use an alternative method of determining heat input. Alternative methods include:

         (I)   Conducting fuel sampling and analysis and monitoring fuel usage.

         (II)   Using boiler efficiency curves and other monitored information such as boiler steam output.

         (III)   Other methods approved by the Department and which meet the requirements in the ‘‘Guidance for Implementation of Emission Monitoring Requirements for the NOx Budget Program.’’

       (E)   Alternative methods for determining heat input are subject to both initial and periodic relative accuracy, and quality assurance testing as prescribed by ‘‘Guidance for Implementation of Emission Monitoring Requirements for the NOx Budget Program.’’

   (10)  If the owner or operator determines NOx emission rate in pounds per million Btu in accordance with paragraph (6)(iii) and heat input rate in MMBtu per hour in accordance with paragraph (7), the two values shall be multiplied to result in NOx emissions in pounds per hour. If the owner or operator determines NOx emissions in ppm and flow in standard cubic feet per hour, the procedures in ‘‘Guidance for Implementation of Emission Monitoring Requirements for the NOx Budget Program’’ may be used to determine NOx emissions of this rule in pounds per hour. This value shall be reported to the NETS.

   (11)  Non-Part 75 sources which have Department approved NOx CEMS reporting in accordance with §  139.101 in units of pounds of NOx per hour may meet the monitoring requirements of paragraph (7); or shall comply with the following:

     (i)   Calibration standards used shall be in accordance with both 40 CFR Part 75, Appendix A, Section 5.2 (relating to concentrations) and with §  139.102(3).

     (ii)   Testing listed in 40 CFR Part 75, Appendix A, Section 6.4 (relating to cycle time/response time test) not already conducted as part of the response time testing in §  139.102(3) shall be conducted.

     (iii)   Bias testing of the relative accuracy test data in accordance with 40 CFR Part 75, Appendix A, Section 6.5 (relating to relative accuracy and bias tests) shall be conducted. Data from previously conducted relative accuracy testing may be used to meet this requirement.

     (iv)   Adjustment of data due to failure of bias test (in accordance with 40 CFR Part 75, Appendix A, Section 7.6.5 (relating to bias adjustment) and Appendix B, Section 2.3.3 (relating to bias adjustment factor)) or relative accuracy greater than 10% but less than or equal to 20% (by multiplying the NOx emissions rate by 1.1), or both, shall be conducted only for reporting to the NOx budget administrator for purposes of this section.

     (v)   A Data Acquisition Handling System verification demonstrating that both the missing data procedures and formulas as applicable to this section shall be conducted.

Source

   The provisions of this §  123.108 adopted October 31, 1997, effective November 1, 1997, 27 Pa.B. 5683.

Cross References

   This section cited in 25 Pa. Code §  123.101 (relating to purpose); 25 Pa. Code §  123.103 (relating to general NOx allowance provisions); 25 Pa. Code §  123.110 (relating to source compliance requirements); 25 Pa. Code §  123.111 (relating to failure to meet source compliance requirements); 25 Pa. Code §  123.112 (relating to source operating permit provision requirements); 25 Pa. Code §  123.113 (relating to source recordkeeping requirements); 25 Pa. Code §  123.115 (relating to initial NOx allowance NOx allocations); 25 Pa. Code §  123.116 (relating to source opt-in provisions); 25 Pa. Code §  123.117 (relating to new NOx affected source provisions); 25 Pa. Code §  123.118 (relating to emission reduction credit provisions); 25 Pa. Code §  123.120 (relating to audit); 25 Pa. Code §  123.121 (relating to NOx Allowance Program transition); and 25 Pa. Code §  145.43 (relating to compliance supplement pool).

§ 123.109. Source emissions reporting requirements.

 (a)  The authorized account representative for each NOx affected source shall submit to the NOx budget administrator, electronically in a format which meets the requirements of the EPA’s Electronic Data Reporting convention, emissions and operations information for each calendar quarter of each year in accordance with the document titled, ‘‘Guidance for Implementation of Emission Monitoring Requirements for the NOx Budget Program.’’

 (b)  Upon permanent shutdown, NOx affected sources may be exempted from this section after receiving written Department approval of a request filed by the authorized account representative for the NOx affected source which identifies the source and date of shutdown.

Source

   The provisions of this §  123.109 adopted October 31, 1997, effective November 1, 1997, 27 Pa.B. 5683.

Cross References

   This section cited in 25 Pa. Code §  123.101 (relating to purpose); 25 Pa. Code §  123.103 (relating to general NOx allowance provisions); 25 Pa. Code §  123.108 (relating to source emissions monitoring requirements); 25 Pa. Code §  123.111 (relating to failure to meet source compliance requirements); 25 Pa. Code §  123.112 (relating to source operating permit provision requirements); 25 Pa. Code §  123.113 (relating to source recordkeeping requirements); 25 Pa. Code §  123.115 (relating to initial NOx allowance NOx allocations); 25 Pa. Code §  123.116 (relating to source opt-in provisions); 25 Pa. Code §  123.117 (relating to new NOx affected source provisions); 25 Pa. Code §  123.118 (relating to emission reduction credit provisions); 25 Pa. Code §  123.120 (relating to audit); 25 Pa. Code §  123.121 (relating to NOx Allowance Program transition); and 25 Pa. Code §  145.43 (relating to compliance supplement pool).

§ 123.110. Source compliance requirements.

 (a)  Each year from November 1 through December 31, inclusive, the authorized account representative shall request the NOx budget administrator to deduct, consistent with §  123.107 (relating to NOx allowance transfer procedures) a designated amount of NOx allowances by serial number, from the NOx affected source’s compliance account in an amount equivalent to the NOx emitted from the NOx affected source during that year’s NOx allowance control period in accordance with the following:

   (1)  Allowances allocated for the current NOx control period may be used without restriction.

   (2)  Allowances allocated for future NOx control periods may not be used.

   (3)  NOx allowances which were allocated for any preceding NOx allowance control period which were not used (banked) may be used in the current control period even if this may result in an unlimited exceedance of the NOx budget. Banked allowances shall be deducted against emissions in accordance with a ratio of NOx allowances to emissions as specified by the NOx budget administrator as follows:

     (i)   If the total NOx allowances remaining in the NATS for all sources for preceding NOx allowance control periods are less than or equal to 10% of the total NOx allowances allocated for that NOx allowance control period, the ratio is 1:1.

     (ii)   If the total NOx allowances remaining in the NATS for all sources for preceding NOx allowance control periods are greater than 10% of the NOx allowances allocated for that NOx allowance control period, the ratio is 2:1 for the portion of banked allowances used for compliance from an account which are in excess of the amount calculated by multiplying the total allowances banked in the account times the PFC (progressive flow control).

 where

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 (b)  If, by the December 31 compliance deadline, the authorized account representative either makes no NOx allowance deduction request, or a NOx allowance deduction request insufficient to meet the requirements of subsection (a), the NOx budget administrator may deduct the necessary number of NOx allowances from the NOx affected source’s compliance account. The NOx budget administrator shall provide written notice to the authorized account representative that NOx allowances were deducted from the source’s account. If the necessary number of NOx allowances is available, the source will be in compliance after the NOx allowance deduction is completed. If there is an insufficient number of NOx allowances available for NOx allowance deduction, §  123.111 (relating to failure to meet source compliance requirements) applies.

 (c)  For each NOx allowance control period, the authorized account representative for the NOx affected source shall submit an annual compliance certification to the Department.

 (d)  The compliance certification shall be submitted no later than the NOx allowance transfer deadline (December 31) of each year.

 (e)  The compliance certification shall contain, at a minimum, the following:

   (1)  An identification of the NOx affected source, including the name, address, the name of the authorized account representative and the NATS account number.

   (2)  A statement indicating whether or not emissions data has been submitted to the NETS in accordance with §  123.108 (relating to source emissions monitoring requirements).

   (3)  A statement indicating whether or not the NOx affected source held sufficient NOx allowances, as determined in subsection (a), in its compliance account for the NOx allowance control period, as of the NOx allowance transfer deadline, to equal or exceed the NOx affected source’s actual emissions and the emissions reported to the NETS for the NOx allowance control period.

   (4)  A statement indicating whether or not the monitoring plan which governs the NOx affected source was followed when monitoring the actual operation of the NOx affected source.

   (5)  A statement indicating that all emissions from the NOx affected source were accounted for, either through the applicable monitoring or through application of the appropriate missing data procedures.

   (6)  A statement indicating whether there were any changes in the method of operation of the NOx affected source or the method of monitoring of the NOx affected source during the current year.

 (f)  The Department may verify compliance by whatever means necessary, including one or more of the following:

   (1)  Inspection of facility operating records.

   (2)  Obtaining information on NOx allowance deduction and transfers from the NATS.

   (3)  Obtaining information on emissions from the NETS.

   (4)  Testing emission monitoring devices.

   (5)  Requiring the NOx affected source to conduct emissions testing in accordance with Chapter 139 (relating to sampling and testing).

Source

   The provisions of this §  123.110 adopted October 31, 1997, effective November 1, 1997, 27 Pa.B. 5683.

Cross References

   This section cited in 25 Pa. Code §  123.101 (relating to purpose); 25 Pa. Code §  123.102 (relating to source NOx allowance requirements and NOx allowance control period); 25 Pa. Code §  123.103 (relating to general NOx allowance provisions); 25 Pa. Code §  123.108 (relating to source emissions monitoring requirements); 25 Pa. Code §  123.111 (relating to failure to meet source compliance requirements); 25 Pa. Code §  123.112 (relating to source operating permit provision requirements); 25 Pa. Code §  123.113 (relating to source recordkeeping requirements); 25 Pa. Code §  123.115 (relating to initial NOx allowance NOx allocations); 25 Pa. Code §  123.116 (relating to source opt-in provisions); 25 Pa. Code §  123.117 (relating to new NOx affected source provisions); 25 Pa. Code §  123.118 (relating to emission reduction credit provisions); 25 Pa. Code §  123.120 (relating to audit); 25 Pa. Code §  123.121 (relating to NOx Allowance Program transition); and 25 Pa. Code §  145.43 (relating to compliance supplement pool).

§ 123.111. Failure to meet source compliance requirements.

 (a)  Failure by the NOx affected source to hold in its compliance account, for a NOx allowance control period, as of the NOx allowance transfer deadline, sufficient NOx allowances equal to or exceeding actual emissions for the NOx allowance control period as specified under §  123.102 (relating to source allowance requirements and NOx allowance control period) shall result in NOx allowance deduction from the NOx affected source’s compliance account at the rate of 3 NOx allowances for every 1 ton of excess emissions. If sufficient allowances meeting the requirements of §  123.110(a) (relating to source compliance requirements) are not available, the source shall provide other sufficient allowances which shall be deducted prior to the beginning of the next NOx allowance control period, otherwise the source may not operate during subsequent control periods.

 (b)  In addition to the NOx allowance deduction required by subsection (a), the Department may enforce the provisions of this section and § §  123.101—123.110 and 123.112—123.120 under the act and the Clean Air Act.

   (1)  For purposes of determining the number of days of violation, any excess emissions for the NOx allowance control period shall presume that each day in the NOx allowance control period constitutes a day in violation (153 days) unless the NOx affected source can demonstrate, to the satisfaction of the Department, that a lesser number of days should be considered.

   (2)  Each ton of excess emissions is a separate violation.

Source

   The provisions of this §  123.111 adopted October 31, 1997, effective November 1, 1997, 27 Pa.B. 5683.

Cross References

   This section cited in 25 Pa. Code §  123.101 (relating to purpose); 25 Pa. Code §  123.103 (relating to general NOx allowance provisions); 25 Pa. Code §  123.108 (relating to source emissions monitoring requirements); 25 Pa. Code §  123.110 (relating to source compliance requirements); 25 Pa. Code §  123.112 (relating to source operating permit provision requirements); 25 Pa. Code §  123.113 (relating to source recordkeeping requirements); 25 Pa. Code §  123.115 (relating to initial NOx allowance NOx allocations); 25 Pa. Code §  123.116 (relating to source opt-in provisions); 25 Pa. Code §  123.117 (relating to new NOx affected source provisions); 25 Pa. Code §  123.118 (relating to emission reduction credit provisions); 25 Pa. Code §  123.120 (relating to audit); 25 Pa. Code §  123.121 (relating to NOx Allowance Program transition); and 25 Pa. Code §  145.43 (relating to compliance supplement pool).

§ 123.112. Source operating permit provision requirements.

 The operating permit required under Chapter 127 (relating to construction, modification, reactivation and operations of sources) shall include a condition requiring compliance with § §  123.101—123.111, 123.113—123.120 and this section (relating to NOx allowance requirements). The NATS compliance account number and the authorized account representative shall be listed on the permit.

Source

   The provisions of this §  123.112 adopted October 31, 1997, effective November 1, 1997, 27 Pa.B. 5683.

Cross References

   This section cited in 25 Pa. Code §  123.101 (relating to purpose); 25 Pa. Code §  123.103 (relating to general NOx allowance provisions); 25 Pa. Code §  123.108 (relating to source emissions monitoring requirements); 25 Pa. Code §  123.111 (relating to failure to meet source compliance requirements); 25 Pa. Code §  123.113 (relating to source recordkeeping requirements); 25 Pa. Code §  123.115 (relating to initial NOx allowance NOx allocations); 25 Pa. Code §  123.116 (relating to source opt-in provisions); 25 Pa. Code §  123.117 (relating to new NOx affected source provisions); 25 Pa. Code §  123.118 (relating to emission reduction credit provisions); 25 Pa. Code §  123.120 (relating to audit); 25 Pa. Code §  123.121 (relating to NOx Allowance Program transition); and 25 Pa. Code §  145.43 (relating to compliance supplement pool).

§ 123.113. Source recordkeeping requirements.

 The owner or operator of a NOx affected source shall maintain for each NOx affected source and for 5 years, or any other period consistent with the terms of the NOx affected source’s operating permit, the measurements, data, reports and other information required by § §  123.101—123.112, 123.114—123.120 and this section.

Source

   The provisions of this §  123.113 adopted October 31, 1997, effective November 1, 1997, 27 Pa.B. 5683.

Cross References

   This section cited in 25 Pa. Code §  123.101 (relating to purpose); 25 Pa. Code §  123.103 (relating to general NOx allowance provisions); 25 Pa. Code §  123.108 (relating to source emissions monitoring requirements); 25 Pa. Code §  123.111 (relating to failure to meet source compliance requirements); 25 Pa. Code §  123.112 (relating to source operating permit provision requirements); 25 Pa. Code §  123.113 (relating to source recordkeeping requirements); 25 Pa. Code §  123.115 (relating to initial NOx allowance NOx allocations); 25 Pa. Code §  123.116 (relating to source opt-in provisions); 25 Pa. Code §  123.117 (relating to new NOx affected source provisions); 25 Pa. Code §  123.118 (relating to emission reduction credit provisions); 25 Pa. Code §  123.120 (relating to audit); 25 Pa. Code §  123.121 (relating to NOx Allowance Program transition); and 25 Pa. Code §  145.43 (relating to compliance supplement pool).

§ 123.114. General NOx allocation provisions.

 (a)  NOx allocations to NOx affected sources may only be made by the Department.

 (b)  Except as provided in §  123.116 (relating to source opt-in provisions), for NOx affected sources identified in Appendix A which shutdown or curtail operations, the source account will continue to receive NOx allowances for each NOx allowance control period.

Source

   The provisions of this §  123.114 adopted October 31, 1997, effective November 1, 1997, 27 Pa.B. 5683.

Cross References

   This section cited in 25 Pa. Code §  123.101 (relating to purpose); 25 Pa. Code §  123.103 (relating to general NOx allowance provisions); 25 Pa. Code §  123.108 (relating to source emissions monitoring requirements); 25 Pa. Code §  123.111 (relating to failure to meet source compliance requirements); 25 Pa. Code §  123.112 (relating to source operating permit provision requirements); 25 Pa. Code §  123.113 (relating to source recordkeeping requirements); 25 Pa. Code §  123.115 (relating to initial NOx allowance NOx allocations); 25 Pa. Code §  123.116 (relating to source opt-in provisions); 25 Pa. Code §  123.117 (relating to new NOx affected source provisions); 25 Pa. Code §  123.118 (relating to emission reduction credit provisions); 25 Pa. Code §  123.120 (relating to audit); 25 Pa. Code §  123.121 (relating to NOx Allowance Program transition); and 25 Pa. Code §  145.43 (relating to compliance supplement pool).

§ 123.115. Initial NOx allowance NOx allocations.

 (a)  The sources contained in Appendix E are subject to the requirements of § §  123.101—123.114, 123.116—123.120 and this section. These sources are allocated NOx allowances for the 1999-2002 NOx allowance control periods as listed in Appendix E.

 (b)  The Department may allocate allowances to Duquesne Light Company’s Phillips and Brunot Island facilities. The allowances allocated to these facilities are limited as follows:

   (1)  The facility shall be fully operational.

   (2)  The allowances allocated to the facility may only be used by the baseline sources located at that facility, and may not be banked or transferred.

   (3)  The allocation to Brunot Island source identification numbers 001—012 may not exceed an aggregate 246 allowances for the period May 1—September 30.

   (4)  The allocation to Phillips Station boilers 1—6 may not exceed an aggregate 1,686 allowances for the period May 1—September 30.

Authority

   The provisions of this §  123.115 amended under section 5(a)(1) of the Air Pollution Control Act (35 P. S. §  4005(a)(1)).

Source

   The provisions of this §  123.115 adopted October 31, 1997, effective November 1, 1997, 27 Pa.B. 5683; amended March 10, 2000, effective March 11, 2000, 30 Pa.B. 1370; amended September 22, 2000, effective September 23, 2000, 30 Pa.B. 4899. Immediately preceding text appears at serial pages (263985) to (263986).

Cross References

   This section cited in 25 Pa. Code §  123.101 (relating to purpose); 25 Pa. Code §  123.103 (relating to general NOx allowance provisions); 25 Pa. Code §  123.108 (relating to source emissions monitoring requirements); 25 Pa. Code §  123.111 (relating to failure to meet source compliance requirements); 25 Pa. Code §  123.112 (relating to source operating permit provision requirements); 25 Pa. Code §  123.113 (relating to source recordkeeping requirements); 25 Pa. Code §  123.116 (relating to source opt-in provisions); 25 Pa. Code §  123.117 (relating to new NOx affected source provisions); 25 Pa. Code §  123.118 (relating to emission reduction credit provisions); 25 Pa. Code §  123.120 (relating to audit); 25 Pa. Code §  123.121 (relating to NOx Allowance Program transition); and 25 Pa. Code §  145.43 (relating to compliance supplement pool).

§ 123.116. Source opt-in provisions.

 (a)  A person who owns, operates, leases or controls a non-NOx affected source located in this Commonwealth may apply to the Department to opt-in that source to become a NOx affected source. For replacement sources, all sources to which production may be shifted to shall be opted-in together.

 (b)  A source which began operations without emission reduction credits transferred from a NOx affected source may become a NOx affected source under the following conditions:

   (1)  Submission of an opt-in application to the Department, including:

     (i)   Documentation of baseline NOx allowance control period emissions which shall be the average of the actual emissions for the preceding two consecutive NOx allowance control periods. The Department may approve selection of an alternative two consecutive NOx allowance control periods within the 5 years preceding the opt-in application if the preceding two control periods are not representative of normal operations. The baseline may not exceed applicable emission limits.

     (ii)   Evidence that the requirements of § §  123.101—123.115, 123.117—123.120 and this section (relating to NOx allowance requirements) can be complied with, including, submission of an emission monitoring plan, designation of an authorized account representative, and that the source is not on the compliance docket established under section 7.1 of the act (35 P. S. §  4005).

   (2)  Submission of NOx allowances established under paragraph (1)(i) or subsection (c) by the Department to the NOx budget administrator.

 (c)  A source which began operations with emission reduction credits from a NOx affected source may become a NOx affected source by complying with subsection (b)(1). To operate the source, NOx allowances shall be acquired by the owner or operator from those available in the NATS.

 (d)  Opt-in sources which opted-in under subsection (b) and which shutdown or curtail operations during any NOx allowance control period within the 5-calendar years after opting-in shall, prior to January 31 following the shutdown or curtailment, surrender to the Department NOx allowances for the current NOx allowance control period equivalent to the difference resulting from the reduction in utilization from the source’s baseline operations as established in subsection (b)(1)(i) between the NOx allowance control period allowance allocation and the emissions reported in accordance with §  123.109 (relating to source emissions reporting requirements). NOx allocations for future NOx allocation control periods shall also be surrendered. NOx allowances which were allocated for any preceding NOx allowance control period which were not used (banked) may not be surrendered. Surrendered NOx allowances shall be retired from the NATS and NOx budget except that upon request by the source owner or operator, the Department may reallocate the NOx allowances to a qualifying replacement source.

 (e)  Opt-in sources which remain in operation for 5- calendar years from the date of opt-in shall have a new baseline and allowance allocation set in accordance with the procedure in subsection (b)(1)(i). This baseline may not exceed the opt-in baseline. Thereafter, the source is not subject to this section.

 (f)  Once electing to opt-in, a source may not revert to a non-NOx affected source unless it is shut down.

Source

   The provisions of this §  123.117 adopted October 31, 1997, effective November 1, 1997, 27 Pa.B. 5683.

Cross References

   This section cited in 25 Pa. Code §  123.101 (relating to purpose); 25 Pa. Code §  123.103 (relating to general NOx allowance provisions); 25 Pa. Code §  123.108 (relating to source emissions monitoring requirements); 25 Pa. Code §  123.111 (relating to failure to meet source compliance requirements); 25 Pa. Code §  123.112 (relating to source operating permit provision requirements); 25 Pa. Code §  123.113 (relating to source recordkeeping requirements); 25 Pa. Code §  123.114 (relating to general NOx allocation provisions); 25 Pa. Code §  123.115 (relating to initial NOx allowance NOx allocations); 25 Pa. Code §  123.117 (relating to new NOx affected source provisions); 25 Pa. Code §  123.118 (relating to emission reduction credit provisions); 25 Pa. Code §  123.120 (relating to audit); 25 Pa. Code §  123.121 (relating to NOx Allowance Program transition); and 25 Pa. Code §  145.43 (relating to compliance supplement pool).

§ 123.117. New NOx affected source provisions.

 (a)  NOx allowances may not be created for new NOx affected sources. New NOx affected sources are sources which are not listed in §  123.115 (relating to initial NOx allowance NOx allocations). The owner or operator of a new NOx affected source shall establish a compliance account prior to the commencement of operations and is responsible to acquire any required NOx allowances from those available in the NATS.

 (b)  Newly discovered NOx affected sources not included in Appendix A which operated at any time between May 1 and September 30, 1990, shall comply with § §  123.101—123.116, 123.118—123.120 and this section (relating to NOx allowance requirements) within 1-calendar year from the date of discovery. For those sources which notify the Department by April 1, 1998, the Department will petition the OTC to include the emissions in the NOx MOU Budget and provide NOx allowances to the source using the historical May 1 to September 30, 1990, emissions reduced as specified in §  123.119(a)(4)(ii) (relating to bonus NOx allowance awards).

Source

   The provisions of this §  123.117 adopted October 31, 1997, effective November 1, 1997, 27 Pa.B. 5683.

Cross References

   This section cited in 25 Pa. Code §  123.101 (relating to purpose); 25 Pa. Code §  123.103 (relating to general NOx allowance provisions); 25 Pa. Code §  123.108 (relating to source emissions monitoring requirements); 25 Pa. Code §  123.111 (relating to failure to meet source compliance requirements); 25 Pa. Code §  123.112 (relating to source operating permit provision requirements); 25 Pa. Code §  123.113 (relating to source recordkeeping requirements); 25 Pa. Code §  123.115 (relating to initial NOx allowance NOx allocations); 25 Pa. Code §  123.116 (relating to source opt-in provisions); 25 Pa. Code §  123.118 (relating to emission reduction credit provisions); 25 Pa. Code §  123.120 (relating to audit); 25 Pa. Code §  123.121 (relating to NOx Allowance Program transition); and 25 Pa. Code §  145.43 (relating to compliance supplement pool).

§ 123.118. Emission reduction credit provisions.

 (a)  NOx affected sources may create, transfer and use emission reduction credits in accordance with Chapter 127 (relating to construction, modification, reactivation and operation of sources) and this section. ERCs may not be used to satisfy NOx allowance requirements.

 (b)  Emission reductions made through overcontrol, curtailment or shutdown for which allowances are banked are not surplus and may not be used to create ERCs.

 (c)  A NOx affected source may transfer NOx ERCs to an NOx affected source if the new or modified NOx affected source’s ozone season (May 1—September 30) allowable emissions do not exceed the ozone season portion of the baseline emissions which were used to generate the NOx ERCs.

 (d)  A NOx affected source may transfer NOx ERCs to a non-NOx affected source under the following conditions:

   (1)  The non-NOx affected source’s ozone season (May 1—September 30) allowable emissions may not exceed the ozone season portion of the baseline emissions which were used to generate the NOx ERCs.

   (2)  The NATS account for NOx affected sources which generated ERCs transferred to non-NOx affected sources, including prior to the date of publication in the Pennsylvania Bulletin, shall have a corresponding number of allowances retired that reflect the transfer of emissions regulated under § §  123.101—123.117, 123.119—123.120 and this section (relating to NOx allowance requirements) to the NOx nonaffected sources. The amount of annual NOx allowances deducted shall be equivalent to that portion of the nonaffected source’s NOx control period allowable emissions which were provided for by the NOx ERCs from the affected source.

   (3)  Allocations for NOx allowance control periods following 2002 to the NOx ERC generating source may not include the allowances identified in paragraph (2).

Source

   The provisions of this §  123.118 adopted October 31, 1997, effective November 1, 1997, 27 Pa.B. 5683.

Cross References

   This section cited in 25 Pa. Code §  123.101 (relating to purpose); 25 Pa. Code §  123.103 (relating to general NOx allowance provisions); 25 Pa. Code §  123.108 (relating to source emissions monitoring requirements); 25 Pa. Code §  123.111 (relating to failure to meet source compliance requirements); 25 Pa. Code §  123.112 (relating to source operating permit provision requirements); 25 Pa. Code §  123.113 (relating to source recordkeeping requirements); 25 Pa. Code §  123.115 (relating to initial NOx allowance NOx allocations); 25 Pa. Code §  123.116 (relating to source opt-in provisions); 25 Pa. Code §  123.117 (relating to new NOx affected source provisions); 25 Pa. Code §  123.120 (relating to audit); 25 Pa. Code §  123.121 (relating to NOx Allowance Program transition); and 25 Pa. Code §  145.43 (relating to compliance supplement pool).

§ 123.119. Bonus NOx allowance awards.

 (a)  The Department will, upon receipt of a complete application by November 1, 1998, award a NOx affected source with bonus NOx allowances for certain creditable emission reductions made during the 1997 and 1998 ozone seasons (May 1—September 30) under the following conditions:

   (1)  Creditable reductions shall be in excess of the OTC MOU reduction requirements and any applicable emission limits including RACT and maximum achievable control technology.

   (2)  Bonus allowances shall be calculated separately for the 1997 and 1998 ozone seasons (May 1—September 30).

   (3)  The actual average ozone season (May 1—September 30) heat input used to calculate the emission reduction may not exceed the average 1995 and 1996 ozone season actual heat input, or if the Department finds that it is more representative of normal operations, the average ozone season (May 1—September 30) actual heat input which occurred during another consecutive 2 years between and including 1991 and 1995.

   (4)  Bonus NOx allowances shall be calculated by multiplying the actual 1997 or 1998, as applicable, average ozone season (May 1—September 30) heat input, times the difference between the following:

     (i)   The after-control emission rate calculated using the average rate occurring during the 1997 or 1998 NOx allowance control.

     (ii)   The lower of the source’s applicable emission rate for NOx expressed in pounds of NOx per MMBtu, or the baseline emission rate established in Appendix A after applying the following reduction, as applicable. The reduction for sources located in the outer zone is 55% or 0.2 lbs/MMBtu whichever is less stringent, and for sources located in the inner zone, 65%, or 0.2 lbs/MMBtu whichever is less stringent. The inner zone includes Berks, Bucks, Chester, Delaware, Montgomery and Philadelphia counties, and the outer zone includes the remaining counties within this Commonwealth.

   (5)  Applications shall include the information necessary to determine that the reductions meet the requirements of this section.

 (b)  On or before May 1, 1999, the Department will publish a report in the Pennsylvania Bulletin which documents the number of bonus NOx allowances awarded.

Source

   The provisions of this §  123.119 adopted October 31, 1997, effective November 1, 1997, 27 Pa.B. 5683.

Cross References

   This section cited in 25 Pa. Code §  123.101 (relating to purpose); 25 Pa. Code §  123.103 (relating to general NOx allowance provisions); 25 Pa. Code §  123.108 (relating to source emissions monitoring requirements); 25 Pa. Code §  123.111 (relating to failure to meet source compliance requirements); 25 Pa. Code §  123.112 (relating to source operating permit provision requirements); 25 Pa. Code §  123.113 (relating to source recordkeeping requirements); 25 Pa. Code §  123.115 (relating to initial NOx allowance NOx allocations); 25 Pa. Code §  123.116 (relating to source opt-in provisions); 25 Pa. Code §  123.117 (relating to new NOx affected source provisions); and 25 Pa. Code §  123.118 (relating to emission reduction credit provisions); 25 Pa. Code §  123.20 (relating to audit); 25 Pa. Code §  123.121 (relating to NOx Allowance Program transition); and 25 Pa. Code §  145.43 (relating to compliance supplement pool).

§ 123.120. Audit.

 (a)  The Department will complete an audit of the program established by § §  123.101—123.119 and this section (relating to NOx allowance requirements) prior to May 1, 2002, and at a minimum every 3 years thereafter. The audit shall include the following:

   (1)  The resulting geographic distribution of emissions as well as the hourly, daily and running average emission totals shall be examined in the context of ozone control requirements. This analysis shall be used in making a determination as to whether the zonal, seasonal and interseasonal trading and banking provisions of the rule require modification to ensure the reductions are as effective as daily emission limits on all sources would be at reducing ozone.

   (2)  Confirmation of emissions reporting accuracy through validation of NOx allowance CEMS and data acquisition systems at the NOx affected source.

   (3)  If emissions in excess of the NOx allowances allocated occurred in any NOx allowance control period, as a result of banking provisions, a determination whether or not the NOx allowance banking provisions require modification or deletion.

   (4)  NOx allowance banking privileges will be examined to determine whether they adversely influenced market availability and price of NOx allowances or created unfair competitive advantages and if so, recommend amendments to rectify these problems.

   (5)  An assessment of whether the program is providing the level of emission reductions included in the current SIP.

 (b)  In addition to the Department audit, the Department may seek a third party audit of the program. The third party audit can be implemented on a state by state basis or can be performed on a region-wide basis under the supervision of the Ozone Transport Commission.

 (c)  The Department will propose regulation revisions consistent with the audit results within 6 months of the completion of the audit.

Source

   The provisions of this §  123.120 adopted October 31, 1997, effective November 1, 1997, 27 Pa.B. 5683.

Cross References

   This section cited in 25 Pa. Code §  123.101 (relating to purpose); 25 Pa. Code §  123.103 (relating to general NOx allowance provisions); 25 Pa. Code §  123.108 (relating to source emissions monitoring requirements); 25 Pa. Code §  123.111 (relating to failure to meet source compliance requirements); 25 Pa. Code §  123.112 (relating to source operating permit provision requirements); 25 Pa. Code §  123.113 (relating to source recordkeeping requirements); 25 Pa. Code §  123.115 (relating to initial NOx allowance NOx allocations); 25 Pa. Code §  123.116 (relating to source opt-in provisions); 25 Pa. Code §  123.117 (relating to new NOx affected source provisions); 25 Pa. Code §  123.118 (relating to emission reduction credit provisions); and 25 Pa. Code §  145.43 (relating to compliance supplement pool).

§ 123.121. NOx Allowance Program transition.

 (a)  NOx allocations for the NOx allowance control periods starting May 1, 2003, will be distributed in accordance with Chapter 145 (relating to interstate pollution transport reduction).

 (b)  The emission limitations and monitoring requirements established in § §  123.101—123.120 are replaced by the requirements in Chapter 145 beginning with the May 1, 2003, control period. If a source has failed to demonstrate compliance with §  123.111 (relating to failure to meet source compliance requirements), the provisions in §  145.54(d) (relating to compliance) shall be used to withhold NOx allowances in calendar year 2003 and beyond. If no NOx allowances are provided to the source under §  145.42 (relating to NOx allowance allocations), the source will be obligated to acquire and retire a number of NOx allowances as specified in §  145.54.

Source

   The provisions of this §  123.121 adopted September 22, 2000, effective September 23, 2000, 30 Pa.B. 4899.

APPENDIX A


Appendix A

Cross References

   This appendix cited in 25 Pa. Code §  123.11 (relating to combustion units).

APPENDIX B


Cross References

   This appendix cited in 25 Pa. Code §  123.13 (relating to processes).

APPENDIX C


Appendix C

Cross References

   This appendix cited in 25 Pa. Code §  123.13 (relating to processes).

APPENDIX D
ALTERNATIVE OPACITY LIMITATION—APPLICATION




Applicable Regulation
Opacity/Mass Limitation
Procedure
A. Sources subject to EPA NSPSOpacity limit specified in NSPSEPA procedure for AOL applies
Opacity limit not specified in NSPSDER procedure will be used to establish AOL at the NSPS level for mass emissions
B. Sources subject to nonattainment area provisions (LAER applies)Emission limitation will be specified in permitDER procedure will be used to establish AOL at the maximum mass emissions rate specified as LAER
C. Sources subject to permit requirements (e.g., BACT)Mass emission rate specific in PAA or permitDER procedure will be used to establish AOL at BACT mass emission rate
No mass emission rate specified in PAA or permit (e.g., equipment specification), 2 cases
 1. No opacity limit specified in PAA or permitNot eligible for AOL
 2. No opacity limit specified in PAA or permit (mass emission rate and opacity limits under DER regulation are assumed to apply)DER procedure will be used to establish AOL at the regulatory emission rate
D. Sources subject only to DER regulations (RACT)—no permit conditions applyMass emission limitation specified in DER regulationDER procedure will be used to establish AOL at the regulatory emission rate
No mass emission limitation specified in DER regulationNot eligible for AOL

   NOTE: Sources incapable of a stack test are ineligible for an AOL
Abbreviations: AOL—alternative opacity limitation
NSPS—New source performance standards
PAA—plan approval application
BACT—best available control technology
LAER—lowest achievable emission rate
RACT—reasonably available control technology
PSD—prevention of significant deterioration

Cross References

   This appendix cited in 25 Pa. Code §  123.45 (relating to alternative opacity limitations).

Source

   The provisions of this Appendix D adopted June 19, 1981, effective June 20, 1981, 11 Pa.B. 1447; corrected June 26, 1981, effective June 20, 1981, 11 Pa.B. 2225.

APPENDIX E



BONUS ALLOWANCE
Baseline
County Facility Combustion Source Name Point ID Allowance NOx lb/MMBtu
Adams Met Edison Hamilton 031 4 0.59
Adams Met Edison Ortanna 031 3 0.59
Adams Metropolitan Edison Company G. E. N Frame Turbine #1 031 17 0.45
Adams Metropolitan Edison Company G. E. N Frame Turbine #2 032 6 0.45
Adams Metropolitan Edison Company G. E. N Frame Turbine #3 033 14 0.45
Allegheny Duquesne Light Company, Cheswick Boiler 001 2,5000.73
Armstrong Penelec—Keystone Boiler No. 1 031 4,334 0.80
Armstrong Penelec—Keystone Boiler No. 2 0323,4390.79
Armstrong West Penn Power Co. Foster Wheeler 031 1,137 0.95
Armstrong West Penn Power Co. Foster Wheeler 032 1,063 1.02
Beaver AES Beaver Valley Partners, Inc. Babcock and Wilcox 032301 0.83
Beaver AES Beaver Valley Partners, Inc. Babcock and Wilcox 033 247 0.83
Beaver AES Beaver Valley Partners, Inc. Babcock and Wilcox 034 286 0.83
Beaver AES Beaver Valley Partners, Inc. Babcock and Wilcox 035 154 0.81
Beaver Penn Power Co.—Bruce Mansfield Boiler Unit 1 031 2,987 0.90
Beaver Penn Power Co.—Bruce Mansfield Foster Wheeler Unit No. 2 032 3,857 0.90
Beaver Penn Power Co.—Bruce Mansfield Foster Wheeler Unit 3 033 3,497 0.70
Beaver Zinc Corporation Of America Coal Boiler 1 034 240 0.80
Beaver Zinc Corporation Of America Coal Boiler 2 035 2030.80
Berks Metropolitan Edison Co.—Titus Unit 1 031 202 0.65
Berks Metropolitan Edison Co.—Titus Unit 2 032 186 0.68
Berks Metropolitan Edison Co.—Titus Unit 3 033 201 0.66
Berks Metropolitan Edison Co.—Titus No. 4 Combustion Turbine 034 2 0.44
Berks Metropolitan Edison Co.—Titus No. 5 Combustion Turbine 035 2 0.44
Blair Penelec—Williamsburg No. 11 Boiler—Rily 031 38 0.87
Bucks PECO Energy—Falls Unit 1 70.67
Bucks PECO Energy—Falls Unit 2 70.67
Bucks PECO Energy—Falls Unit 360.67
Bucks PECO Energy—Croyden Croyden—Turbine #1103111 0.70
Bucks PECO Energy—Croyden Croyden—Turbine #120327 0.70
Bucks PECO Energy—Croyden Croyden—Turbine #21 03344 0.70
Bucks PECO Energy—Croyden Croyden—Turbine #22 034 20 0.70
Bucks PECO Energy—Croyden Croyden—Turbine #31 035 11 0.70
Bucks PECO Energy—Croyden Croyden—Turbine #32 036 14 0.70
Bucks PECO Energy—Croyden Croyden—Turbine #41 037 8 0.70
Bucks PECO Energy—Croyden Croyden—Turbine #42 038 38 0.70
Bucks PECO Energy—Fairless Hills Power House Boiler No. 304363 0.26
Bucks PECO Energy—Fairless Hills Power House Boiler No. 404414 0.27
Bucks PECO Energy—Fairless Hills Power House Boiler No. 504573 0.26
Bucks PECO Energy—Fairless HillsPower House Boiler No. 604684 0.26
Cambria Cambria CoGen Company A Boiler 031 199 0.24
Cambria Cambria CoGen Company B Boiler 032 210 0.23
Cambria Colver Power Project 409 0.20
Cambria Ebensburg Power Company CFB Boiler 205 0.08
Carbon Panther Creek Energy Facility Boiler 1 119 0.12
Carbon Panther Creek Energy Facility Boiler 2 116 0.12
Chester PECO Energy—Cromby Boiler No 1 031 246 0.82
Chester PECO Energy—Cromby Boiler No 2 032 186 0.28
Clarion Piney Creek Project CFB Boiler 121 0.18
Clearfield Penelec—Shawville Babcock Wilcox Boiler 031 979 1.22
Clearfield Penelec—Shawville Babcock Wilcox Boiler 032 945 1.21
Clearfield Penelec—Shawville Combustion Engineering 033 850 0.86
Clearfield Penelec—Shawville Combustion Engineering 034 692 0.87
Clinton International Paper Co. 1 Riley Stoker Vo-Sp 033 145 0.55
Clinton International Paper Co. 2 Riley Stoker Vo-Sp 034 145 0.55
Clinton PP&L—Lock Haven CT 1 3 0.49
Columbia Penelec—Benton 002 1 2.33
Columbia Penelec—Benton 003 1 2.93
Cumberland Metropolitan Edison Company G.E. N Frame Turbine 031 9 0.45
Cumberland Metropolitan Edison Company G.E. N Frame Turbine 032 11 0.45
Cumberland PP&L—West Shore CT 1 3 0.49
Cumberland PP&L—West Shore CT 2 3 0.49
Dauphin PP&L—Harrisburg CT 1 3 0.49
Dauphin PP&L—Harrisburg CT 2 4 0.49
Dauphin PP&L—Harrisburg CT 3 4 0.49
Dauphin PP&L—Harrisburg CT 4 4 0.49
Delaware Tosco Refinery 7 Boiler 032 330.37
Delaware Tosco Refinery 8 Boiler 033 540.48
Delaware Tosco Refinery Platformer Heater 038 180 0.55
Delaware Tosco Refinery 543 Crude Heater 044 101 0.55
Delaware Tosco Refinery 544 Crude Heater 045 115 0.55
Delaware PECO Energy— Eddystone No. 1 Boiler 031 660 0.54
Delaware PECO Energy— Eddystone No. 2 Boiler 032 430 0.55
Delaware PECO Energy— Eddystone No. 3 Boiler 033 255 0.28
Delaware PECO Energy— Eddystone No. 30 Gas Turbine 039 2 0.48
Delaware PECO Energy— Eddystone No. 40 Gas Turbine 040 1 0.49
Delaware PECO Energy— Eddystone No. 4 Boiler 041 248 0.28
Delaware Kimberly—Clark Boiler No. 9 034 12 0.52
Delaware Kimberly—Clark 10 Culm Cogen. Fbc Plant 035 84 0.08
Delaware Sun Refining & Marketing 089 86 0.09
Delaware FPL Energy 090 145 0.08
Erie General Electric Co. B & W Boiler No. 2 032 26 1.01
Erie International Paper Company Coal Fired Boiler No. 21 037 68 0.58
Erie Norcon Power Partners Turbine 1 001 50 0.07
Erie Norcon Power Partners Turbine 2 002 50 0.07
Erie Penelec—Front Street Erie City Iron Works No. 7 031 5 0.92
Erie Penelec—Front Street Erie City Iron Works No. 8 032 5 0.90
Erie Penelec—Front Street Comb. Eng. Boiler No. 9 033 133 0.57
Erie Penelec—Front Street Comb. Eng. Boiler No. 10 034 133 0.57
Greene West Penn Power— Hatfield’s Ferry Babcock & Wilcox 031 3,969 1.04
Greene West Penn Power— Hatfield’s Ferry Babcock & Wilcox 032 3,694 1.04
Greene West Penn Power— Hatfield’s Ferry Babcock & Wilcox 033 2,154 1.04
Indiana Penelec—Conemaugh Boiler No. 1 031 3,288 0.76
Indiana Penelec—Conemaugh Boiler No. 2 032 4,187 0.76
Indiana Penelec—Homer City Boiler No. 1-Foster Whelr 031 3,160 1.20
Indiana Penelec—Homer City Boiler No. 2-Foster Whelr 032 3,978 1.20
Indiana Penelec—Homer City Boiler No. 3-B.& W. 033 2,924 0.62
Indiana Penelec—Seward Boiler No. 12 (B&W) 032 144 0.84
Indiana Penelec—Seward Boiler No. 14 (B&W) 033 146 0.83
Indiana Penelec—Seward Boiler No. 15 (Comb.Eng.) 931 672 0.75
Lackawanna Archbald Power Corporation Cogen 81 0.05
Lancaster PP&L—Holtwood Unit 17 Foster Wheeler 934 806 1.20
Lawrence Penn Power Co.—New Castle Foster Wheeler 031 108 0.91
Lawrence Penn Power Co.—New Castle B.W. Boiler 032 97 0.91
Lawrence Penn Power Co.—New Castle Babcock And Wilcox 033 185 0.91
Lawrence Penn Power Co.—New Castle Babcock And Wilcox 034 339 0.91
Lawrence Penn Power Co.—New Castle Babcock And Wilcox 035 620 0.91
Lehigh PP&L—Allentown CT 1 2 0.49
Lehigh PP&L—Allentown CT 2 3 0.49
Lehigh PP&L—Allentown CT 3 3 0.49
Lehigh PP&L—Allentown CT 4 3 0.49
Lycoming PP&L—Williamsport CT 1 3 0.49
Lycoming PP&L—Williamsport CT 2 3 0.49
Luzerne Continental Energy Associates Turbine 267 0.13
Luzerne Continental Energy Associates HRSG 128 0.20
Luzerne UGI Corp.—Hunlock Power Foster Wheeler 031 374 0.95
Luzerne PP&L—Jenkins CT 1 3 0.49
Luzerne PP&L—Jenkins CT 2 2 0.49
Luzerne PP&L—Harwood CT 1 3 0.49
Luzerne PP&L—Harwood CT 2 3 0.49
Monroe Met Edison Shawnee 031 3 0.59
Montgomery Merck Sharp & Dohme Cogen II Gas Turbine 039 79 0.16
MontgomeryPECO Energy—MoserUnit 1 7 0.67
MontgomeryPECO Energy—MoserUnit 2 7 0.67
MontgomeryPECO Energy—MoserUnit 3 6 0.67
Montour PP&L—Montour Montour No. 1 031 3,568 0.85
Montour PP&L—Montour Montour No. 2 032 4,696 1.07
Montour PP&L—Montour Aux.Start-Up Boiler No. 1 033 9 0.17
Montour PP&L—Montour Aux.Start-Up Boiler No. 2 034 7 0.17
Northampton Bethlehem Steel Corp. Boiler 1 Boiler House 2 041 91 0.23
Northampton Bethlehem Steel Corp. Boiler 2 Boiler House 2 042 91 0.23
Northampton Bethlehem Steel Corp. Boiler 3 Boiler House 2 067 92 0.23
Northampton Met Edison Co.—Portland Unit No. 1 031 462 0.59
Northampton Met Edison Co.—Portland Unit No. 2 032 657 0.66
Northampton Met Edison Co.—Portland Combustion Turbine No. 3 033 1 0.53
Northampton Met Edison Co.—Portland Combustion Turbine No. 4 034 6 0.53
Northampton Northampton Generating Company Boiler 001 209 0.10
Northampton PP&L—Martins Creek Foster-Wheeler Unit No. 1 031 492 1.01
Northampton PP&L—Martins Creek Foster-Wheeler Unit No. 2 032 459 0.91
Northampton PP&L—Martins Creek C-E Unit No. 3 033 835 0.51
Northampton PP&L—Martins Creek C-E Unit No. 4 034 739 0.51
Northampton PP&L—Martins Creek No. 4b Auxiliary Boiler 036 0 0.17
Northampton PP&L—Martins Creek Combustion Turbine No. 1 037 3 0.02
Northampton PP&L—Martins Creek Combustion Turbine No. 2 038 3 0.02
Northampton PP&L—Martins Creek Combustion Turbine No. 3 039 3 0.02
Northampton PP&L—Martins Creek Combustion Turbine No. 4 040 3 0.02
Northumber-
 land
Foster Wheeler Mt. Carmel Cogen Cogen 031 195 0.10
Philadelphia Allied Signal 052 54 0.46
Philadelphia PECO Energy—Richmond Unit 91 037 28 0.60
Philadelphia PECO Energy—Richmond Unit 92 038 37 0.60
Philadelphia PECO Energy—Delaware No. 71 Boiler 013 112 0.45
Philadelphia PECO Energy—Delaware No. 81 Boiler 014 130 0.45
Philadelphia PECO Energy—Delaware No. 9 Gas Turbine 018 2 0.67
Philadelphia PECO Energy—Schuylkill No. 1 Boiler 003 175 0.28
Philadelphia PECO Energy—Schuylkill No. 11 Gas Turbine 008 0 0.67
Philadelphia Trigen Energy Co— Sansom 001 31 0.45
Philadelphia Trigen Energy Co— Sansom 002 27 0.45
Philadelphia Trigen Energy Co— Sansom 003 12 0.45
Philadelphia Trigen Energy Co— Sansom 004 15 0.45
Philadelphia Trigen Energy Co— Schuylkill 001 0 0.28
Philadelphia Trigen Energy Co— Schuylkill 002 0 0.28
Philadelphia Trigen Energy Co— Schuylkill 005 0 0.45
Philadelphia U. S. Naval Base 098 1 0.14
Philadelphia U. S. Naval Base 099 1 0.14
Philadelphia Sun Oil—Girard Point GP Boiler 37 02-2,3 87 0.33
Philadelphia Sun Oil—Girard Point GP Boiler 38 02-4,5 87 0.33
Philadelphia Sun Oil—Girard Point GP Boiler 39 02-6,7 87 0.33
Philadelphia Sun Oil—Girard Point GP Boiler 40 02-8,9 116 0.33
Philadelphia Sun Oil—Girard Point GP F-1 002-2,
3,4 
91 0.27
Philadelphia Sun Oil—Point Breeze PB 3H-1 19/20 43 0.15
Philadelphia Grays Ferry Project Combustion Turbine 125
Philadelphia Grays Ferry Project Heat Recovery Steam Gen 21
Philadelphia Grays Ferry Project Boiler 25 80
Schuylkill Gilberton Power Company Boiler 333 0.17
Schuylkill Northeastern Power Company CFB Boiler 201 0.06
Schuylkill Schuylkill Energy Resources Boiler 031 348 0.20
Schuylkill Westwood Energy Properties Boiler 134 0.17
Schuylkill Wheelabrator Frackville Energy Co Boiler 203 0.14
Schuylkill PP&L—Fishback CT 1 2 0.49
Schuylkill PP&L—Fishback CT 2 2 0.49
Snyder PP&L—Sunbury Sunbury SES Unit 1a 031 294 0.98
Snyder PP&L—Sunbury Sunbury SES Unit 1b 032 294 0.98
Snyder PP&L—Sunbury Sunbury SES Unit 2a 033 294 0.83
Snyder PP&L—Sunbury Sunbury SES Boiler 2b 034 294 0.83
Snyder PP&L—Sunbury Sunbury SES Unit No. 3 035 679 0.93
Snyder PP&L—Sunbury Sunbury SES Unit No. 4 036 821 0.99
Snyder PP&L—Sunbury Combustion Turbine 1 039 3 0.49
Snyder PP&L—Sunbury Combustion Turbine 2 040 3 0.49
Tioga Penelec—Tioga 031 3 0.48
Venango Scrubgrass Power Plant Unit 1 031 181 0.14
Venango Scrubgrass Power Plant Unit 2 032 178 0.15
Warren Penelec—Warren Boiler No. 1 031 76 0.62
Warren Penelec—Warren Boiler No. 2 032 73 0.64
Warren Penelec—Warren Boiler No. 3 033 77 0.61
Warren Penelec—Warren Boiler No. 4 034 80 0.61
Warren Penelec—Warren 001 10 0.69
Washington Duquesne Light Co.— Elrama No. 1 Boiler 031 333 0.87
Washington Duquesne Light Co.— Elrama No. 2 Boiler 032 332 0.90
Washington Duquesne Light Co.— Elrama No. 3 Boiler 033 445 0.87
Washington Duquesne Light Co.— Elrama No. 4 Boiler 034 1,013 0.89
Washington West Penn Power Co.— Mitchell Combustion Eng Coal Unit 034 929 0.72
Wayne Penelec—Wayne 031 11 0.84
Wyoming Procter & Gamble Paper Products Co. Westinghouse 251B10 035 245 0.68
York Glatfelter, P.H. Co. Number 4 Power Boiler 034 127 0.80
York Glatfelter, P.H. Co. Number 1 Power Boiler 035 85 0.80
York Glatfelter, P.H. Co. Number 5 Power Boiler 036 237 0.29
York Met Edison Tolna 031 4 0.59
York Met Edison Tolna 032 4 0.59
York PP&L—Brunner Island Brunner Island 2 032 1,470 0.69
York PP&L—Brunner Island Brunner Island Unit 1 931 1,290 0.67
York PP&L—Brunner Island Brunner Island Unit 3 933 2,906 0.78

Source

   The provisions of this Appendix E adopted October 31, 1997, effective November 1, 1997, 27 Pa.B. 5683; amended March 10, 2000, effective March 11, 2000, 30 Pa.B. 1370. Immediately preceding text appears at serial pages (237287) to (237300).

STANDARDS FOR CONTAMINANTS MERCURY EMISSIONS



   Editor’s Note: In PPL Generation, LLC v. Com., Department of Environmental Protection, 986 A.2d 48 (Supreme 2009), the Pennsylvania Supreme Court declared 25 Pa. Code § §  123.201—123.215 (the ‘‘PA Mercury Rule’’) invalid.

§ 123.201. [Reserved].


Authority

   The provisions of this §  123.201 issued under section 5(a)(1) of the Air Pollution Control Act (35 P. S. §  4005(a)(1)); reserved under section 5 of the Air Pollution Control Act (35 P. S. §  4005).

Source

   The provisions of this §  123.201 adopted February 16, 2007, effective February 17, 2007, 37 Pa.B. 883; reserved November 12, 2010, effective November 13, 2010, 40 Pa.B. 6517. Immediately preceding text appears at serial page (347963).

§ 123.202. [Reserved].


Authority

   The provisions of this §  123.202 issued under section 5(a)(1) of the Air Pollution Control Act (35 P. S. §  4005(a)(1)); reserved under section 5 of the Air Pollution Control Act (35 P. S. §  4005).

Source

   The provisions of this §  123.202 adopted February 16, 2007, effective February 17, 2007, 37 Pa.B. 883; reserved November 12, 2010, effective November 13, 2010, 40 Pa.B. 6517. Immediately preceding text appears at serial pages (347963) to (347964) and (326271) to (326274).

§ 123.203. [Reserved].


Authority

   The provisions of this §  123.203 issued under section 5(a)(1) of the Air Pollution Control Act (35 P. S. §  4005(a)(1)); reserved under section 5 of the Air Pollution Control Act (35 P. S. §  4005).

Source

   The provisions of this §  123.203 adopted February 16, 2007, effective February 17, 2007, 37 Pa.B. 883; reserved November 12, 2010, effective November 13, 2010, 40 Pa.B. 6517. Immediately preceding text appears at serial page (326275).

§ 123.204. [Reserved].


Authority

   The provisions of this §  123.204 issued under section 5(a)(1) of the Air Pollution Control Act (35 P. S. §  4005(a)(1)); reserved under section 5 of the Air Pollution Control Act (35 P. S. §  4005).

Source

   The provisions of this §  123.204 adopted February 16, 2007, effective February 17, 2007, 37 Pa.B. 883; reserved November 12, 2010, effective November 13, 2010, 40 Pa.B. 6517. Immediately preceding text appears at serial pages (326275) to (326276).

§ 123.205. [Reserved].


Authority

   The provisions of this §  123.205 issued under section 5(a)(1) of the Air Pollution Control Act (35 P. S. §  4005(a)(1)); reserved under section 5 of the Air Pollution Control Act (35 P. S. §  4005).

Source

   The provisions of this §  123.205 adopted February 16, 2007, effective February 17, 2007, 37 Pa.B. 883; reserved November 12, 2010, effective November 13, 2010, 40 Pa.B. 6517. Immediately preceding text appears at serial pages (326276) to (326278).

§ 123.206. [Reserved].


Authority

   The provisions of this §  123.206 issued under section 5(a)(1) of the Air Pollution Control Act (35 P. S. §  4005(a)(1)); reserved under section 5 of the Air Pollution Control Act (35 P. S. §  4005).

Source

   The provisions of this §  123.206 adopted February 16, 2007, effective February 17, 2007, 37 Pa.B. 883; reserved November 12, 2010, effective November 13, 2010, 40 Pa.B. 6517. Immediately preceding text appears at serial pages (326278) to (326281).

§ 123.207. [Reserved].


Authority

   The provisions of this §  123.207 issued under section 5(a)(1) of the Air Pollution Control Act (35 P. S. §  4005(a)(1)); reserved under section 5 of the Air Pollution Control Act (35 P. S. §  4005).

Source

   The provisions of this §  123.207 adopted February 16, 2007, effective February 17, 2007, 37 Pa.B. 883; reserved November 12, 2010, effective November 13, 2010, 40 Pa.B. 6517. Immediately preceding text appears at serial pages (326281) to (326286).

§ 123.208. [Reserved].


Authority

   The provisions of this §  123.208 issued under section 5(a)(1) of the Air Pollution Control Act (35 P. S. §  4005(a)(1)); reserved under section 5 of the Air Pollution Control Act (35 P. S. §  4005).

Source

   The provisions of this §  123.208 adopted February 16, 2007, effective February 17, 2007, 37 Pa.B. 883; reserved November 12, 2010, effective November 13, 2010, 40 Pa.B. 6517. Immediately preceding text appears at serial pages (326286) to (326287).

§ 123.209. [Reserved].


Authority

   The provisions of this §  123.209 issued under section 5(a)(1) of the Air Pollution Control Act (35 P. S. §  4005(a)(1)); reserved under section 5 of the Air Pollution Control Act (35 P. S. §  4005).

Source

   The provisions of this §  123.209 adopted February 16, 2007, effective February 17, 2007, 37 Pa.B. 883; reserved November 12, 2010, effective November 13, 2010, 40 Pa.B. 6517. Immediately preceding text appears at serial pages (326287) to (326289).

§ 123.210. [Reserved].


Authority

   The provisions of this §  123.210 issued under section 5(a)(1) of the Air Pollution Control Act (35 P. S. §  4005(a)(1)); reserved under section 5 of the Air Pollution Control Act (35 P. S. §  4005).

Source

   The provisions of this §  123.210 adopted February 16, 2007, effective February 17, 2007, 37 Pa.B. 883; reserved November 12, 2010, effective November 13, 2010, 40 Pa.B. 6517. Immediately preceding text appears at serial pages (326289) to (326293).

§ 123.211. [Reserved].


Authority

   The provisions of this §  123.211 issued under section 5(a)(1) of the Air Pollution Control Act (35 P. S. §  4005(a)(1)); reserved under section 5 of the Air Pollution Control Act (35 P. S. §  4005).

Source

   The provisions of this §  123.211 adopted February 16, 2007, effective February 17, 2007, 37 Pa.B. 883; reserved November 12, 2010, effective November 13, 2010, 40 Pa.B. 6517. Immediately preceding text appears at serial pages (326293) to (326295).

§ 123.212. [Reserved].


Authority

   The provisions of this §  123.212 issued under section 5(a)(1) of the Air Pollution Control Act (35 P. S. §  4005(a)(1)); reserved under section 5 of the Air Pollution Control Act (35 P. S. §  4005).

Source

   The provisions of this §  123.212 adopted February 16, 2007, effective February 17, 2007, 37 Pa.B. 883; reserved November 12, 2010, effective November 13, 2010, 40 Pa.B. 6517. Immediately preceding text appears at serial pages (326295) to (326296).

§ 123.213. [Reserved].


Authority

   The provisions of this §  123.213 issued under section 5(a)(1) of the Air Pollution Control Act (35 P. S. §  4005(a)(1)); reserved under section 5 of the Air Pollution Control Act (35 P. S. §  4005).

Source

   The provisions of this §  123.213 adopted February 16, 2007, effective February 17, 2007, 37 Pa.B. 883; reserved November 12, 2010, effective November 13, 2010, 40 Pa.B. 6517. Immediately preceding text appears at serial pages (326296) to (326297).

§ 123.214. [Reserved].


Authority

   The provisions of this §  123.214 issued under section 5(a)(1) of the Air Pollution Control Act (35 P. S. §  4005(a)(1)); reserved under section 5 of the Air Pollution Control Act (35 P. S. §  4005).

Source

   The provisions of this §  123.214 adopted February 16, 2007, effective February 17, 2007, 37 Pa.B. 883; reserved November 12, 2010, effective November 13, 2010, 40 Pa.B. 6517. Immediately preceding text appears at serial pages (326297) to (326298).

§ 123.215. [Reserved].


Authority

   The provisions of this §  123.215 issued under section 5(a)(1) of the Air Pollution Control Act (35 P. S. §  4005(a)(1)); reserved under section 5 of the Air Pollution Control Act (35 P. S. §  4005).

Source

   The provisions of this §  123.215 adopted February 16, 2007, effective February 17, 2007, 37 Pa.B. 883; reserved November 12, 2010, effective November 13, 2010, 40 Pa.B. 6517. Immediately preceding text appears at serial pages (326298) to (326299).



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