[27 Pa.B. 1829]
[Continued from previous Web Page] § 123.110. Source compliance requirements.
(a) Each year during the period November 1 through December 31, inclusive, the authorized account representative shall request the NOx budget administrator to deduct, consistent with § 123.104 (d) (relating to source authorized account representative requirements) 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 in the OTR NOx budget for preceding NOx allowance control periods are less than 110% 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 in the OTR NOx budget for preceding NOx allowance control periods are 110% or greater than the NOx allowances allocated for that NOx allowance control period, the ratio is 2:1 for the portion of banked allowances in an account which are in excess of the amount calculated by multiplying the total allowances banked in the account times the PFC:
(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 it's 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 operated to measure 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).
§ 123.111. Failure to meet source compliance requirements.
(a) Failure by the NOx affected source to hold in its compliance account, for any 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)(2) (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--123.121 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.
§ 123.112. Source operating permit provision requirements.
The operating permit required under Chapter 127 (relating to construction, modification, reactivation and operation of sources) shall prohibit the source from emitting NOx during each NOx allowance control period in excess of the amount of NOx allowances held in the source's compliance account for the NOx allowance control period as of the NOx allowance transfer deadline. The NATS compliance account number and the authorized account representative shall be listed on the permit.
§ 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--123.121 and this section.
§ 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 which shutdown after an allocation has been made to the source, the source account will continue to receive NOx allowances for each NOx allowance control period.
§ 123.115. Initial NOx allowance NOx allocations.
The sources contained in Appendix A are subject to the requirements of this subchapter. These sources are allocated NOx allowances for the 1999--2002 NOx allowance control periods as listed in the Appendix. Except as provided in § 123.120 (relating to audit), if no allocation is specified for the control periods beyond 2002, the current allocations continue indefinitely.
§ 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--123.121 and this section 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 an NOx affected source may become an 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 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 MOU 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.
§ 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--123.121 and this section within 1-calendar year from the date of discovery. For those sources which notify the Department by ____(Editor's Note: The blank refers to a date 6 months after the effective date of adoption of this proposal), 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 § 123.116(b)(2)(i) (relating to source opt-in provisions).
§ 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.
(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 a NOx affected source if the new or modified NOx affected source's ozone season 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 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 shall be reduced to reflect the transfer of emissions regulated under §§ 123.101--123.117, 123.119--123.121 and this section 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).
§ 123.119. Bonus NOx allowance awards.
(a) The Department may, upon receipt of a complete application by October 1, 1998, award a NOx affected source with bonus NOx allowances for certain emission reductions which are in excess of the OTC MOU reduction requirements and any applicable emission limits including RACT, and MACT, made during the 1997 and 1998 ozone seasons (May 1--September 30).
(b) Bonus NOx allowances shall be calculated by multiplying the actual total heat input for the entire ozone season times the difference between the following:
(1) The after-control emission rate calculated using the average rate occurring during the 1997 or 1998 NOx allowance control.
(2) 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, and for sources located in the inner zone, 65%, or 0.2 lbs/MMBtu whichever is less. The inner zone includes Berks, Bucks, Chester, Delaware, Montgomery and Philadelphia counties, and the outer zone includes the remaining counties within this Commonwealth.
(c) Applications shall include all information necessary to determine that the reductions meet the requirements of this section.
(d) 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.
§ 123.120. Audit.
(a) The Department will complete an audit of the program established by §§ 123.101--123.119, 123.121 and this section (relating to NOx allowance requirements) prior to May 1, 2002, and at a minimum every 3 years thereafter. The audit shall including 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. If they are not, the NOx allocations in § 123.115 (relating to initial NOx allowance NOx allocations) may be modified to provide for this level of effectiveness.
(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 State Implementation Plan (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 operation of the program will be continuously monitored by the Department. The Department may, after notice in the Pennsylvania Bulletin and providing for a 60-day period of public comment, condition, limit, suspend or terminate any NOx allowances or authorization to emit which the NOx allowance represents if the following apply:
(1) Emissions in excess of the NOx allowances allocated for a NOx allowance control period occur.
(2) NOx allowance banking privileges have adversely influenced factors including, but not limited to, market availability, or price of NOx allowances, or created unfair competitive advantages.
(3) The program is not providing the level of emission reductions included in the SIP.
(d) The Department may modify the allowance allocation as provided in this section through the following procedure:
(1) The Department will provide written notice to the affected source.
(2) The Department will publish a notice in the Pennsylvania Bulletin providing for an opportunity for public comment. The notice will describe the proposed revisions and provide the name, address and telephone number of the person from whom the text of the proposed revisions can be obtained.
(3) The comment period will be at least 30 days from the date of the publication of the notice in paragraph (2).
(4) After the public comment period, the Department will evaluate the comments and finalize the proposed revisions to the allocations.
§ 123.121. Additional requirements for independent power producers.
(a) An independent power producer identified in Appendix A that emits NOx, during any NOx allowance control period at a level less than the allowances allocated to the independent power producer for the NOx allowance control period shall retain 10% of the unused allowances from the current NOx allowance control period allocation in the independent power producer's NATS compliance account for any present or future use. The remaining 90% of the unused allowances from the current NOx allowance control period allocation shall be transferred on or before December 31 preceding the NOx allowance control period to an account administered by the Department for economic growth and prosperity in this Commonwealth.
(b) Notwithstanding the provisions of subsection (a), an independent power producer identified in Appendix A that, after February 18, 1997, installs or installed an additional control device that reduces emissions of NOx shall retain, in the independent producers' NATS compliance account for any present or future use, all of the unused allowances allocated to the independent power producer during any NOx control period resulting from operation of the additional control device.
Appendix A
County Facility Combustion Source Name Point ID Allow-
anceBaseline NOx
lb/MMBtuBaseline
MMBtuAdams Met Edison Hamilton 031 4 0.59 18,716 Adams Met Edison Ortanna 031 3 0.59 13,130 Adams Metropolitan Edison Company G.E. N Frame Turbine #1 031 17 0.45 89,908 Adams Metropolitan Edison Company G.E. N Frame Turbine #2 032 6 0.45 29,243 Adams Metropolitan Edison Company G.E. N Frame Turbine #3 033 14 0.45 74,249 Allegheny Duquesne Light Company, Brunot Boiler 001 0 0.48 2,492 Allegheny Duquesne Light Company, Brunot Boiler 002 1 0.48 3,136 Allegheny Duquesne Light Company, Brunot Boiler 003 1 0.49 2,674 Allegheny Duquesne Light Company, Brunot Boiler 004 0 0.48 2,156 Allegheny Duquesne Light Company, Brunot Boiler 006 1 0.48 6,818 Allegheny Duquesne Light Company, Brunot Boiler 008 2 0.48 9,380 Allegheny Duquesne Light Company, Cheswick Boiler 001 2,116 0.61 15,025,580 Armstrong Penelec - Keystone Boiler No. 1 031 4,101 0.80 25,149,236 Armstrong Penelec - Keystone Boiler No. 2 032 3,694 0.70 22,657,898 Armstrong West Penn Power Co. Foster Wheeler 031 1,141 0.95 5,355,101 Armstrong West Penn Power Co. Foster Wheeler 032 1,066 1.02 5,007,467 Beaver AES Beaver Valley Partners, Inc. Babcock and Wilcox 032 314 0.83 1,747,462 Beaver AES Beaver Valley Partners, Inc. Babcock and Wilcox 033 257 0.83 1,431,342 Beaver AES Beaver Valley Partners, Inc. Babcock and Wilcox 034 297 0.83 1,655,847 Beaver AES Beaver Valley Partners, Inc. Babcock and Wilcox 035 123 0.81 683,951 Beaver Penn Power Co. - Bruce Mansfield Boiler Unit 1 031 2,996 0.90 16,618,929 Beaver Penn Power Co. - Bruce Mansfield Foster Wheeler Unit No. 2 032 3,870 0.90 21,464,786 Beaver Penn Power Co. - Bruce Mansfield Foster Wheeler Unit 3 033 3,507 0.70 19,455,843 Beaver Zinc Corporation Of America Coal Boiler 1 034 241 0.80 1,380,627 Beaver Zinc Corporation Of America Coal Boiler 2 035 204 0.80 1,168,776 Berks Metropolitan Edison Co. - Titus Unit 1 031 205 0.65 1,836,587 Berks Metropolitan Edison Co. - Titus Unit 2 032 183 0.68 1,632,072 Berks Metropolitan Edison Co. - Titus Unit 3 033 202 0.66 1,805,003 Berks Metropolitan Edison Co. - Titus No. 4 Combustion Turbine 034 2 0.44 20,010 Berks Metropolitan Edison Co. - Titus No. 5 Combustion Turbine 035 2 0.44 15,484 Blair Penelec - Williamsburg No. 11 Boiler - Rily 031 38 0.87 200,874 Bucks PECO Energy - Croyden Croyden - Turbine #11 031 11 0.70 42,451 Bucks PECO Energy - Croyden Croyden - Turbine #12 032 7 0.70 26,382 Bucks PECO Energy - Croyden Croyden - Turbine #21 033 44 0.70 175,640 Bucks PECO Energy - Croyden Croyden - Turbine #22 034 20 0.70 81,649 Bucks PECO Energy - Croyden Croyden - Turbine #31 035 11 0.70 42,534 Bucks PECO Energy - Croyden Croyden - Turbine #32 036 14 0.70 54,905 Bucks PECO Energy - Croyden Croyden - Turbine #41 037 8 0.70 30,191 Bucks PECO Energy - Croyden Croyden - Turbine #42 038 37 0.70 152,094 Bucks United States Steel Corp., The Power House Boiler No. 3 043 63 0.26 655,625 Bucks United States Steel Corp., The Power House Boiler No. 4 044 14 0.27 147,330 Bucks United States Steel Corp., The Power House Boiler No. 5 045 73 0.26 756,980 Bucks United States Steel Corp., The Power House Boiler No. 6 046 85 0.26 871,810 Cambria Cambria CoGen Company A Boiler 031 200 0.24 2,003,177 Cambria Cambria CoGen Company B Boiler 032 212 0.23 2,116,233 Cambria Colver Power Project 411 0.20 4,112,640 Cambria Ebensburg Power Company CFB Boiler 206 0.08 2,058,858 Cambria Ebensburg Power Company Aux Boiler 1 0.13 5,236 Carbon Panther Creek Energy Facility Boiler 1 116 0.12 1,543,574 Carbon Panther Creek Energy Facility Boiler 2 117 0.12 1,553,778 Chester PECO Energy - Cromby Boiler No 1 031 247 0.82 1,660,770 Chester PECO Energy - Cromby Boiler No 2 032 187 0.28 1,257,120 Clarion Piney Creek Project CFB Boiler 122 0.18 1,217,989 Clearfield Penelec - Shawville Babcock Wilcox Boiler 031 832 1.22 3,737,976 Clearfield Penelec - Shawville Babcock Wilcox Boiler 032 807 1.21 3,624,416 Clearfield Penelec - Shawville Combustion Engineering 033 1,015 0.86 4,558,942 Clearfield Penelec - Shawville Combustion Engineering 034 823 0.87 3,697,889 Clinton International Paper Co. 1 Riley Stoker Vo-Sp 033 143 0.55 1,220,703 Clinton International Paper Co. 2 Riley Stoker Vo-Sp 034 142 0.55 1,218,878 Clinton International Paper Co. 037 33 0.32 283,298 Columbia Penelec - Benton 002 2 2.33 2,661 Columbia Penelec - Benton 003 1 2.93 2,330 Cumberland Metropolitan Edison Company G.E. N Frame Turbine #1 031 9 0.45 46,665 Cumberland Metropolitan Edison Company G.E. N Frame Turbine #1 032 11 0.45 55,480 Delaware BP Oil, Inc. 7 Boiler 032 35 0.37 331,917 Delaware BP Oil, Inc. 8 Boiler 033 58 0.48 535,337 Delaware BP Oil, Inc. 038 191 0.55 1,789,455 Delaware PECO Energy - Eddystone No. 1 Boiler 031 664 0.54 5,571,014 Delaware PECO Energy - Eddystone No. 2 Boiler 032 432 0.55 3,629,294 Delaware PECO Energy - Eddystone No. 3 Boiler 033 256 0.28 2,153,713 Delaware PECO Energy - Eddystone No. 10 Gas Turbine 037 1 0.49 9,464 Delaware PECO Energy - Eddystone No. 20 Gas Turbine 038 1 0.48 7,560 Delaware PECO Energy - Eddystone No. 30 Gas Turbine 039 2 0.48 19,502 Delaware PECO Energy - Eddystone No. 40 Gas Turbine 040 1 0.49 9,450 Delaware PECO Energy - Eddystone No. 4 Boiler 041 249 0.28 2,089,539 Delaware Scott Paper Co. Boiler No. 9 034 12 0.52 264,600 Delaware Scott Paper Co. 10 Culm Cogen. Fbc Plant 035 75 0.08 1,602,169 Delaware Sun Refining & Marketing 089 46 0.09 1,211,002 Delaware Sun Refining & Marketing 090 185 0.08 4,927,837 Elk Penntech Papers, Inc. B&W Model Pm106 Boiler #6 038 0 0.00 0 Elk Penntech Papers, Inc. B & W #81 Boiler 040 103 0.83 570,989 Elk Penntech Papers, Inc. B&W #82 Boiler 041 109 0.83 603,471 Erie General Electric Co. B & W Boiler No. 2 032 26 1.01 587,180 Erie International Paper Company Coal Fired Boiler No. 21 037 40 0.58 321,958 Erie International Paper Company Recovery Boiler No.22 040 32 0.55 262,300 Erie Norcon Power Partners Turbine 1 001 50 0.07 1,483,488 Erie Norcon Power Partners Turbine 2 002 50 0.07 1,483,488 Erie Penelec - Front Street Erie City Iron Works No.7 031 5 0.92 38,964 Erie Penelec - Front Street Erie City Iron Works No.8 032 5 0.90 39,881 Erie Penelec - Front Street Comb. Eng. Boiler No.9 033 134 0.57 1,033,388 Erie Penelec - Front Street Comb. Eng. Boiler No.10 034 134 0.57 1,033,528 Greene West Penn Power - Hatfield's Ferry Babcock & Wilcox 031 3,981 1.04 15,502,912 Greene West Penn Power - Hatfield's Ferry Babcock & Wilcox 032 3,705 1.04 14,429,251 Greene West Penn Power - Hatfield's Ferry Babcock & Wilcox 033 2,162 1.04 8,416,290 Indiana Penelec - Conemaugh Boiler No. 1 031 3,305 0.76 20,130,686 Indiana Penelec - Conemaugh Boiler No. 2 032 4,194 0.76 25,543,024 Indiana Penelec - Homer City Boiler No. 1-Foster Whelr 031 2,349 1.20 11,325,278 Indiana Penelec - Homer City Boiler No. 2-Foster Whelr 032 3,191 1.20 15,382,211 Indiana Penelec - Homer City Boiler No. 3- B.& W. 033 4,554 0.62 21,951,003 Indiana Penelec - Seward Boiler No. 12 (B&W) 032 141 0.79 849,307 Indiana Penelec - Seward Boiler No. 14 (B&W) 033 134 0.83 809,011 Indiana Penelec - Seward Boiler No. 15 (Comb.Eng.) 931 689 0.75 4,155,275 Lackawanna Archbald Power Corporation Cogen 82 0.05 818,013 Lancaster PP&L - Holtwood Unit 17 Foster Wheeler 934 808 1.05 3,553,318 Lawrence Penn Power Co. - New Castle Foster Wheeler 031 108 0.91 553,994 Lawrence Penn Power Co. - New Castle B.W. Boiler 032 97 0.91 498,559 Lawrence Penn Power Co. - New Castle Babcock And Wilcox 033 185 0.91 947,292 Lawrence Penn Power Co. - New Castle Babcock And Wilcox 034 340 0.91 1,737,996 Lawrence Penn Power Co. - New Castle Babcock And Wilcox 035 623 0.91 3,183,091 Luzerne Continental Energy Associates Turbine 269 0.13 2,687,577 Luzerne Continental Energy Associates HRSG 129 0.20 1,288,248 Luzerne UGI Corp. - Hunlock Power Foster Wheeler 031 375 0.95 1,821,127 Monroe Met Edison Shawnee 031 3 0.59 15,285 Montgomery Merck Sharp & Dohme Cogen II Gas Turbine 039 79 0.16 1,028,875 Montour PP&L - Montour Montour No. 1 031 3,586 0.77 18,669,673 Montour PP&L - Montour Montour No. 2 032 4,704 0.98 24,489,052 Montour PP&L - Montour Aux.Start-Up Boiler No. 1 033 9 0.17 44,436 Montour PP&L - Montour Aux.Start-Up Boiler No. 2 034 7 0.17 34,076 Northampton Bethlehem Steel Corp. Boiler 1 Boiler House 2 041 92 0.23 Confidential Northampton Bethlehem Steel Corp. Boiler 2 Boiler House 2 042 92 0.23 Confidential Northampton Bethlehem Steel Corp. Boiler 3 Boiler House 2 067 93 0.23 Confidential Northampton Met Edison Co. - Portland Unit No. 1 031 494 0.59 3,593,611 Northampton Met Edison Co. - Portland Unit No. 2 032 629 0.66 4,578,297 Northampton Met Edison Co. - Portland Combustion Turbine No. 3 033 1 0.53 9,795 Northampton Met Edison Co. - Portland Combustion Turbine No. 4 034 6 0.53 40,931 Northampton Northampton Generating Company Boiler 001 210 0.10 4,208,112 Northampton PP&L - Martins Creek Foster-Wheeler Unit No. 1 031 409 1.19 2,825,705 Northampton PP&L - Martins Creek Foster-Wheeler Unit No. 2 032 449 0.91 3,102,923 Northampton PP&L - Martins Creek C-E Unit No. 3 033 825 0.51 5,696,956 Northampton PP&L - Martins Creek C-E Unit No. 4 034 743 0.50 5,132,553 Northampton PP&L - Martins Creek No. 3a Auxiliary Boiler 035 1 0.17 4,592 Northampton PP&L - Martins Creek No. 4b Auxiliary Boiler 036 1 0.17 2,394 Northampton PP&L - Martins Creek Combustion Turbine No. 1 037 30 0.02 206,640 Northampton PP&L - Martins Creek Combustion Turbine No. 2 038 30 0.02 206,640 Northampton PP&L - Martins Creek Combustion Turbine No. 3 039 30 0.02 206,640 Northampton PP&L - Martins Creek Combustion Turbine No. 4 040 30 0.02 206,640 Northumberland Foster Wheeler Mt. Carmel Cogen Cogen 031 181 0.10 1,814,911 Philadelphia Allied Chemical Corp Boiler 050 9 0.44 90,250 Philadelphia Allied Chemical Corp Boiler 051 12 0.63 125,819 Philadelphia Allied Chemical Corp Boiler 052 56 0.50 565,480 Philadelphia Container Corporation Of America Boiler 001 201 0.10 4,344,433 Philadelphia PECO Energy 037 28 0.60 117,455 Philadelphia PECO Energy 038 37 0.60 156,375 Philadelphia PECO Energy - Delaware 013 111 0.45 918,037 Philadelphia PECO Energy - Delaware 014 129 0.45 1,066,091 Philadelphia PECO Energy - Delaware 015 1 0.67 7,089 Philadelphia PECO Energy - Delaware 016 1 0.67 9,452 Philadelphia PECO Energy - Delaware 017 1 0.67 11,259 Philadelphia PECO Energy - Delaware 018 2 0.67 15,012 Philadelphia PECO Energy - Schuylkill 003 175 0.28 1,459,923 Philadelphia PECO Energy - Schuylkill 007 1 0.67 9,285 Philadelphia PECO Energy - Schuylkill 008 0 0.67 1,946 Philadelphia Phila Thermal - Sansom 001 31 0.45 318,459 Philadelphia Phila Thermal - Sansom 002 27 0.45 280,748 Philadelphia Phila Thermal - Sansom 003 12 0.45 126,824 Philadelphia Phila Thermal - Sansom 004 15 0.45 155,123 Philadelphia Phila Thermal - Schuylkill 001 49 0.28 511,191 Philadelphia Phila Thermal - Schuylkill 002 22 0.28 228,162 Philadelphia Phila Thermal - Schuylkill 005 24 0.45 248,138 Philadelphia Sun Refining And Marketing 1 Of 2 006 49 0.45 513,255 Philadelphia Sun Refining And Marketing 1 Of 2 007 81 0.44 837,798 Philadelphia Sun Refining And Marketing 1 Of 2 038 57 0.41 589,265 Philadelphia Sun Refining And Marketing 1 Of 2 039 57 0.41 589,265 Philadelphia U. S. Naval Base 098 1 0.14 14,294 Philadelphia U. S. Naval Base 099 0 0.14 1,960 Schuylkill Gilberton Power Company Boiler 335 0.17 3,352,372 Schuylkill Northeastern Power Company CFB Boiler 202 0.06 2,022,148 Schuylkill Northeastern Power Company Aux Boiler 0 0.27 1,396 Schuylkill Schuylkill Energy Resources Boiler 031 435 0.20 4,349,117 Schuylkill Westwood Energy Properties Boiler 135 0.17 1,351,408 Schuylkill Wheelabrator Frackville Energy Co Boiler 205 0.14 2,046,694 Snyder PP&L - Sunbury Sunbury SES Unit 1a 031 310 0.85 1,679,317 Snyder PP&L - Sunbury Sunbury SES Unit 1b 032 310 0.85 1,679,317 Snyder PP&L - Sunbury Sunbury SES Unit 2a 033 309 0.72 1,679,197 Snyder PP&L - Sunbury Sunbury SES Boiler 2b 034 309 0.72 1,679,197 Snyder PP&L - Sunbury Sunbury SES Unit No. 3 035 653 0.88 3,542,301 Snyder PP&L - Sunbury Sunbury SES Unit No. 4 036 795 0.93 4,312,439 Snyder PP&L - Sunbury Diesel Generator 1 037 0 3.39 709 Snyder PP&L - Sunbury Diesel Generator 2 038 0 3.23 806 Snyder PP&L - Sunbury Combustion Turbine 1 039 3 0.49 14,581 Snyder PP&L - Sunbury Combustion Turbine 2 040 3 0.49 14,581 Tioga Penelec - Tioga 031 3 0.48 30,267 Vernango Scrubgrass Power Plant Unit 1 031 182 0.14 1,816,817 Venango Scrubgrass Power Plant Unit 2 032 179 0.15 1,790,997 Warren Penelec - Warren Boiler No. 1 031 76 0.62 569,825 Warren Penelec - Warren Boiler No. 2 032 73 0.64 546,534 Warren Penelec - Warren Boiler No. 3 033 77 0.61 572,007 Warren Penelec - Warren Boiler No. 4 034 80 0.61 596,377 Warren Penelec - Warren 001 11 0.69 77,943 Washington Duquesne Light Co. - Elrama No. 1 Boiler 031 334 0.87 1,116,538 Washington Duquesne Light Co. - Elrama No. 2 Boiler 032 333 0.90 1,114,175 Washington Duquesne Light Co. - Elrama No. 3 Boiler 033 446 0.87 1,490,615 Washington Duquesne Light Co. - Elrama No. 4 Boiler 034 1,017 0.89 3,398,150 Washington McGraw-Edison Co. Foster-Wheeler 032 0 0.00 0 Washington Washington Power Co. Boiler 1 155 0.15 2,068,438 Washington Washington Power Co. Boiler 2 155 0.15 2,068,438 Washington West Penn Power Co. - Mitchell Combustion Eng Coal Unit 034 932 0.72 5,968,482 Wayne Penelec - Wayne 031 11 0.84 62,736 Westmoreland Monessen Inc. Boiler House 031 42 0.15 587,980 Wyoming Procter & Gamble Paper Products Co. Westinghouse 251B10 035 246 0.68 1,654,800 York Glatfelter, P. H. Co. 1 Recovery Boiler & Dce 031 82 0.17 663,631 York Glatfelter, P. H. Co. Number 4 Power Boiler 034 122 0.80 978,985 York Glatfelter, P. H. Co. Number 1 Power Boiler 035 62 0.80 500,276 York Glatfelter, P. H. Co. Number 5 Power Boiler 036 199 0.29 1,602,840 York Met Edison Tolna 031 4 0.59 20,492 York Met Edison Tolna 032 4 0.59 19,306 York PP&L - Brunner Island Brunner Island 2 032 1,476 0.63 10,260,211 York PP&L - Brunner Island Brunner Island Unit 1 931 1,300 0.61 9,037,867 York PP&L - Brunner Island Brunner Island Unit 3 933 2,910 0.71 20,238,806
[Pa.B. Doc. No. 97-557. Filed for public inspection April 11, 1997, 9:00 a.m.]
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