Diameter (ft): 2.1 Height (ft): 45 Gas Velocity (ft/ sec): 25.8 Gas Temperature (F): 576 Response: The intent was to represent the gas velocity and temperature as some generally representative value. The temperature will be changed as requested.

Permitting Status In regards to permitting status, Ticona manages all metals (with the exception of chromium) and chlorine under Adjusted Tier I. Chromium is managed under Tier III.

In regards to the Report Name/ Date under Permitting Status, the report is entitled:

Trial Bum/ Risk Burn Report Boiler 16 Celanese Engineering Resins, Inc. September 1998 The report was prepared by TRC Environmental Corporation (TRC). TRC was also responsible for performing the testing on June 23 25, 1998.

Condition 10 (1018C10) In regards to Condition Description and Condition Content under Condition 10 of the Permitting Status, Condition 10 is better described as the maximum combustion temperature condition during the 1996 Certification of Compliance (CoC) performed on Boiler 16. The 1996 CoC maximum combustion temperature condition data was submitted with the 1998 Trial Burn/ Risk Burn Report as "data in lieu of trial burn". The 1996 CoC was submitted in its entirety as an appendix in the 1998 Trial Burn/ Risk Burn Report.

In addition, the content of Condition 10 is better described by saying that the feed analysis included all10 BIF metals (not chromium only), chlorides, and ash. Particulate matter, carbon monoxide, and hexavalent and total chromium were measured in the stack exhaust.

Condition 12 (1018C12)

In regards to Condition Description under Condition 12 of the Permitting Status, Condition 12 is better described as the risk burn condition at maximum liquid waste feedrates and minimum natural gas flowrate.

STACK GAS EMISSIONS Condition 1018C10 The maximum hourly rolling average carbon monoxide (CO) concentration for Run 1 of Condition 1018C10 is 0.6 ppmv corrected to 7% oxygen and not 0.06 ppmv as reported in the NODA database. Consequently. the Condition Average for CO (MHRA) under Condition 1018C10 is 10.9 ppmv instead of 10.7 ppmv as reported in the NODA database. Please reference: Table 2.3 Boiler 16 Process Operating Conditions During BIF Test  Condition No. 3 in the Appendix entitled Condition 1018C10.

The Sampling Train 1 for PM was reported as not being available for Condition 1018C10. This information can be found in the 1996 CoC which was submitted as an appendix in the 1998 Trial Burn/ Risk Burn Report. As a convenience, please reference: Table 2.19 PM Sampling Train Parameters and Stack Conditions  Test Condition 3 in the Appendix entitled Condition 1018C10.

The Sampling Train for hexavalent chromium was reported as not being available for Condition 1018C10. This information can be found in the 1996 CoC which was submitted as an appendix in the 1998 Trial Burn/ Risk Burn Report. As a convenience, please reference: Table 2.22 Hexavalent and Total Chromium Sampling Train Parameters and Stack Conditions  Test Condition 3 in the Appendix entitled Condition 1018C10.

Condition 1018C11 Condition 1018C11 is the minimum temperature condition of the 1998 Trial Bum/ Risk Burn Report. One of the primary purposes of this condition is to demonstrate the necessary Destruction Removal Efficiency (DRE). Ticona selected toluene and chlorobenzene as the two principal organic hazardous constituents (POHCs) to measure in the feed and in the spike material fed to Boiler 16. In addition, the stack exhaust was tested to determine the concentrations of the two POHCs so that the DRE could then be determined. The NODA did not report the total amount of the two POHCs that was fed to Boiler 16 instead it only presented the contribution attributable to the waste feed burned in Boiler 16. The total feedrates (feed + spike) and the emission rates of the POHCs can be found in the 1998 Trial Burn/ Risk Burn Report. As a convenience, please reference: Table 4 7 Destruction Removal Efficiency Results in the Appendix entitled Condition 1018C11.

FEEDSTREAMS Condition 1018C10 The only feed stream that was described for Condition 1018C10 was the liquid waste stream fed to Boiler 16. In addition to the liquid waste stream, Ticona fed natural gas, an ash modifier; and particulate matter and hexavalent chromium spike feeds to Boiler 16. Ticona adds Fuelsolv FS850 (ash modifier) along with the liquid waste stream to enhance the particulate matter characteristics in the case where particulate is generated as a solid in the firebox chamber. The ash modifier is ratioed to the liquid waste feedrate and the liquid waste ash content. On average, 0.13 gallons per hour of the ash modifier is added continuously to the liquid waste stream. The stream feedrates and their respective ash, chlorine and metals feed rates may be found in the 1996 CoC which was submitted as an appendix in the 1998 Trial Burn/ Risk Bum Report. As a convenience, please reference: Table 2.7 Liquid Waste Feed Stream Characterization and Constituent Feed Rates Test Condition No. 3: Table 2.10 Ash Modifier Feed Stream Characterization and Constituent Feed Rates Test Condition No. 3; and Table 2.13 Total Feed Rates of Ash, Chlorine, and Metals to Boiler 16  Condition No. 3 in the Appendix entitled Condition 1018C10.

The Stack Gas Flowrate and Oxygen Content for Condition 1018C10 was reported as not being available. In feet, the stack gas flowrate and the oxygen content were actually collected in both the particulate matter; and the hexavalent and total chromium sampling trains during the 1996 CoC. As a convenience, please reference: Table 2.19 PM Sampling Train Parameters and Stack Conditions  Test Condition 3 and Table 2.22 Hexavalent and Total Chromium Sampling Train Parameters and Stack Conditions  Test Condition 3 in the Appendix entitled Condition 1018C10.

Condition 1018C11 The only feed stream that was described for condition 1018C11 was the liquid waste stream fed to Boiler 16. In addition to this stream, Ticona fed natural gas, and an ash modifier at a feedrate of ~499 grams per hour to Boiler 16. The ash modifier is described above in Condition 1018C10.

...( section removed and addressed in Section 4.8 (feedrate non detect calculation unclear) Firing Rate In regards to the firing rate calculation for Condition 1018C12, the natural gas firing rate contribution was not included. During this condition, 12.05 thousand standard cubic feet per hour (mscfh) of natural gas was fed to Boiler 16. This feed rate accounts for ~12.5 million BTU per hour (MMBTU/ hr) of additional firing rate capacity based on an estimated heating value of 1040 BTU/ scf for natural gas. The total firing rate for Boiler 16 during Condition 1018C12 is approximately 67.5 MMBTU/ hr when considering the liquid waste and natural gas feedrates.

In addition, Boiler 16 is always operated with a minimum of at least 12 15 mscfh of natural gas. The natural gas feedrates during Conditions 1018C10 and 1018C11 is available in the 1998 Trial Burn/ Risk Burn Report.

Feedrate MTEC Calculations Once the discrepancies recommended above in the FEEDSTREAMS section for Condition 1018C12 are implemented regarding the corrections to the barium and mercury feedrates in the liquid waste stream and the antimony feedrate in the ash modifier as well as the addition of "nd" (non detect) to the thallium feedrate in the liquid waste stream and the antimony feedrate in the ash modifier, the Feedrate MTEC calculations should then be mathematically correct.

BIF Tier I Feedrates The BIF Tier I feedrate limits were initially submitted in Volume 8 of the 1998 Trial Burn/ Risk Burn Report. Since then, the BIF Tier I feedrate limits were subsequently revised and resubmitted to the Texas Natural Resource Conservation Commission in August 1999. For convenience, the BIF Tier I feedrate limits are documented below in grams per hour and in micrograms per dry standard cubic meter (ug/ dscm) using the same basis as used for the Feedrate MTEC Calculations.

Constituent BIF Tier I Feedrate (grams/ hour) BIF Tier I Feedrate (ug/ dscm)

Chlorine 531.37 22099.5 Antimony 398.52 16574.3 Barium 66420.66 2762406.9 Lead 119.56 4972.4 Mercury 106.27 4419.7 Silver 3985.24 165744.4 Thallium 398.52 16574.3 Arsenic 0.45 18.7 Beryllium 0.47 19.5 Cadmium 0.47 19.5 Hexavalent chromium is managed under Tier III. During Condition 1018C10, Ticona demonstrated that at a spiked chromium feedrate of 13.66 g/ hr that it could meet its emission rate limit of 0.77 g/ hr. Similarly, Ticona demonstrated during Condition 1018C10 that at a spiked ash feedrate of 3844 g/ hr that it could meet the BIF PM limit of 0.08 grains/ dscf. The 1996 CoC maximum combustion temperature condition data (Condition 1018C10) was submitted with the 1998 Trial Burn/ Risk Burn Report as "data in lieu of trial burn". The 1996 CoC was submitted in its entirety as an appendix in the 1998 Trial Burn/ Risk Burn Report.

Response EPA has reviewed the requested data base edits. Responses to these requested changes or additions are documented in Table 3.

5.16 Rubicon Inc. (Phase II ID # 812, 813, 814, and 815)

Rubicon (17)

Comments on NODA Phase II Database Rubicon Inc.

These comments will be for the following sources, 812, 813, 814, and 815 as identified in the NODA Phase II Database. Comments will be organized for each source by each spreadsheet for that source.

General Comment Overall the accuracy of the database is good with respect to Rubicon's sources, 812, 813, 814, and 815. The only discrepancies noted were incorrect entries of data or missing information.

Source 812  TDI Boiler, Rubicon Inc.

Source Spreadsheet  812 Database Combustor Characteristics: Waste heat boiler, 30 MMBtu/ hr, installed 1985, 25,000 lb/ hr steam @ 215 psig Comment 1 A more accurate description for Combustor Characteristics is: Turbulent burner chamber, closed coupled to a watertube waste heat boiler, 30 MMBtu/ hr, installed 1985, 25,000 lb/ hr steam @ 215 psig.

Requested Action: Update the Combustor Characteristics with this description.

Database Stack Height: (blank)

Comment 2 The stack height for this source is 100 ft.

Requested Action: Update the stack height to read 100 ft.

Database Permit Status: Tier I adjusted except Cr+ 6 Comment 3 The permit status should be the following: Permit Status; Tier I adjusted except Cr+ 6 and HCl/ Cl2.

Requested Action: Update the permit status to reflect this change.

Feed Spreadsheet  812 Database 812C2, Run 5, LUWA Bottoms Total Chorine feed rate: 265 lbs/ hr.

Comment 4 The reported number for 812C2, Run 5, LUWA Bottoms Total Chorine feed rate is 267 lbs/ hr. This is found in Table 2 12 of the TDI Boiler Compliance Trial Burn Report submitted on December 29, 1997.

Requested Action; Update 812C2, Run 5, LUWA Bottoms Total Chorine feed rate to the reported number of 267 lbs/ hr.

Database 812C2, Average LUWA Bottoms Measured Chorine feed rate: 95 lbs/ hr.

Comment 5 The reported number for 812C2, Average LUWA Bottoms Measured Chorine feed rate is 96.8 lbs/ hr. This is found in Table 2 12 of the TDI Boiler Compliance Trial Burn Report submitted on December 29, 1997.

Requested Action: Update 812C2, Average LUWA Bottoms Measured Chorine feed rate to the reported number of 96.8 lbs/ hr.

Database The 812C2 LUWA Bottoms Chromium feed rate for all three runs are listed below:

812C2 Run 2 Run 4 Run 5 Avg Stream Description LUWA bottoms LUWA bottoms LUWA bottoms LUWA bottoms Chromium lb/ hr 5.00E 03 5.00E 03 5.00E 03 5.00E 03 Comment 6 The reported 812C2 LUWA Bottoms Chromium feed rate for all three runs are:

812C2 Run 2 Run 4 Run 5 Avg Stream Description LUWA bottoms LUWA bottoms LUWA bottoms LUWA bottoms Chromium lb/ hr 5.36E 03 5.48E 03 5.15E 03 5.33E 03 This is found in Table 2 12 of the TDI Boiler Compliance Trial Burn Report submitted on December 29, 1997.

Requested Action: Update 812C2 LUWA Bottoms Chromium feed rate to the reported numbers for this condition.

...( section removed and addressed in Section 4.9)

Process Spreadsheet  812 Database 812C1 Scrubber L/ G Ratio gal/ kcaf?

Comment 8 The units for Scrubber L/ G Ratio are lb/ lb.

Requested Action: Update the unit for Scrubber L/ G to lb/ lb.

Database 812C2 Scrubber L/ G Ratio gal/ kcaf?

Comment 9 See Comment 8 Database 813C3 Scrubber L/ G Ratio gal/ kcaf?

Comment 10 See Comment 8 ...( section removed and addressed in Section 4.9)

Source 813 Aniline II Boiler, Rubicon Inc.

Source Spreadsheet 813 Database Combustor Characteristics: Steam of 25,000 lb/ hr @ 350 psig Comment 12 A more accurate description for Combustor Characteristics is: Turbulent burner chamber closed coupled to a water tube waste heat boiler and economizer, Steam of 25,000 lb/ hr @ 350 psig.

Requested Action: Update the Combustor Characteristics with this description.

Database Stack Velocity ft/ min Comment 13 The units for stack velocity should be ft/ sec.

Requested Action: Update the units for stack velocity to ft/ sec.

Database Permitting Status: (blank)

Comment 14 The permitting status for this unit is Adjusted Tier I.

Requested Action: Update the permit status to reflect this change.

Emission Spreadsheet  813 Database 813C1 Run 4 there is no indication of Soot Blowing Comment 15 During Run 4 of 813C1 there were 6 minutes of Soot Blowing as reported in Section 3.2 of the Aniline II Compliance Trial Burn Report Submitted on December 29, 1997.

Requested Action: Update the database to reflect this information.

Feed Spreadsheet  813 Database 813C1 Average Condition Hydrogen feed rate: 105 lbs/ hr Comment 16 The reported value for the Average Condition Hydrogen feed rate is 106 lbs/ hr. This is found in Tables 2 1 through 2 3 of the Aniline II Boiler Compliance Trial Burn Report submitted on December 29, 1997.

Requested Action: Update the Average Condition Hydrogen feed rate to the reported value.

...( section removed and addressed in Section 4.9)

Source 814 DPA I Superheater, Rubicon Inc.

Source Spreadsheet  814 Database Combuster: Boiler Comment 19 A better description for this unit is Process Heater/ Boiler. The primary function of the DPA I Superheater is to superheat a raw material used in the production of Diphenylamine. This unit does produce steam but only a small portion of the total heat input is utilized for steam production.

Requested Action: Update the Combustor section to reflect this description.

Database Stack Height: (blank)

Comment 20 The Stack Height for this source is 75 ft.

Requested Action: Update the stack height to read 75 ft.

Database Velocity ft/ min Comment 21 See Comment 13.

Emissions Spreadsheet  814 Database The values for stack gas flow rate, moisture and temperature from the814C2 (B run ) are listed below.

814C2 (B Runs) 1B 2B 3B Cond Avg Sampling Train 1 PCDD PCDF Stack Gas Flowrate dscfm 5254 5561 5518 5444 Moisture % 60.9 57.1 59.7 59.2 Temperature °F 697 678 685 687 Comment 22 The reported values for stack gas flow rate, moisture and temperature from the 814C2 (B runs) are listed below:

814C2 (B Runs) 1B 2B 3B Cond Avg Sampling Train 1 PCDD PCDF Stack Gas Flowrate dscfm 5207 5273 5416 5299 Moisture % 60.41 60.07 59.38 59.95 Temperature °F 682 678 685 681.7 These Values are found in Table 3 35 of the Risk Assessment Trial Burn Report Submitted on December 29, 1997.

Requested Action: Update the stack gas flow rate, moisture and temperature from the 814C2 (B runs) to the reported values.

Feed Spreadsheet 814 Database The values for the ash feed rate from the 814C2 ( A runs) are listed below:

Comment 23 The reported values for the ash feed rate from the 814C2 (A runs) are listed below:

814C2 (A runs) Run 3A Run 4A Run 5A Cond. Avg.

Ash lb/ hr 1.09 1.17 1.14 1.13 These values are found in Tables 2 1 through 2 3 of the Risk Assessment Trial Burn Report Submitted on December 29, 1997.

Requested Action: Update the ash feed rate from the 814C2 (A runs) to the reported values.

...( section removed and addressed in Section 4.9)

Source 815  DPA II Superheater, Rubicon Inc.

Source Spreadsheet 815 Database Combuster: Boiler Comment 26 A better description for this unit is Process Heater/ Boiler. The primary function of the DPA I Superheater is to superheat a raw material used in the production of Diphenylamine. This unit does produce steam but only a small portion of the total heat input is utilized for steam production.

Requested Action: Update the Combustor section to reflect this description.

Database Combustor Characteristics: Turbulent burner chamber Comment 27 A more accurate description for this unit is Turbulent burner chamber, separate tube banks. Requested Action: Update the Combustor Characteristics with this description.

Database Stack velocity ft/ min Comment 28 See Comment 13 Database Stack Height: (blank)

Comment 29 The stack height for this unit is 80.5 ft.

Requested Action: Update the stack height to read 80.5 ft.

Feed Spreadsheet  815 Database The firing rate for 815C1 is stated as 17.0 MMBTU/ hr Comment 30 The reported firing rate for 815C1 is 15.7 MMBTU/ hr as shown in Tables 2 1 through 2 3 of the DPA II Compliance Trial Burn Report submitted on December 29, 1997.

Requested Action: Update the firing rate for 815C1 to the reported value.

...( section removed and addressed in Section 4.9)

Response EPA has reviewed the requested data base edits. Responses to these requested changes or additions are documented in Table 3.

5.17 Equistar Chemicals, LP. (Phase II ID # 774)

Equistar (18)

Information from the 1998 BIF recertification report was used to develop the proposed NESHAP database; however, some information is missing or has not been accurately entered into the database and has been revised. These changes include:

Inclusion of Boiler Nos. 1,2 and 4 as sister facilities  Addition of exhaust stack characteristics  Correction of gas flowrate and addition of percent moisture and gas  temperature of sampling train 1 and stack gas flowrate.

 Correction of mass feedrate of liquid hazardous waste and metal feedrates and addition of heating value for the natural gas stream for both operating conditions 774C1 and 774C2.

The values from the "Feedrate MTEC Calculations" contained in the 774C1 section for each of the ten BIF metals, ash, chlorine, SVM and LVM have not been corrected for the revised information and will need to be recalculated.

As instructed in the Federal Register, enclosed are an original and two copies of the comment response which include a copy of the Certificate of Compliance forms and pages containing the additional information from the 1998 BIF recertification report. Also, a diskette containing the revised NODA electronic file using Microsoft Excel 97® has also been enclosed with each comment package.

Response EPA has reviewed the requested data base edits. Responses to these requested changes or additions are documented in Table 3.

5.18 Dow Chemical (Phase II ID # 729, 851, 730, 733, 786, 788, 842, 843, 844, 845, 848, 849, 2017, 2018, 2020)

The Dow Chemical Company (19)

The Dow Chemical Company appreciates this opportunity to provide comments on the database the United States Environmental Protection Agency (EPA) presented in the Notice of Data Availability (NODA) for Future Phase 11 Combustion Rulemaking found at 65FR 39581 dated June 27, 2000. It is Dow's understanding that this is the database the Agency will use to propose the National Emission Standards for Hazardous Air Pollutants (NESHAPS) for hazardous waste burning boilers, halogen acid furnaces, and sulfuric acid recovery furnaces. We appreciate the EPA efforts to develop reasonable regulations and are pleased to be able to contribute our thoughts and concerns. Dow has reviewed the information for its Facilities included in the database and offer comments on the accuracy and completeness of the database. Enclosed are an original and two copies of Dow's comments. We appreciate EPA consideration of Dow comments.

In reviewing the database presented in the NODA, Dow has identified a number of inaccuracies and suggested corrections to eliminate those inaccuracies. To facilitate the Agency's review we have provided general comments followed by detail findings that are sorted by the facility EPA phase 11 identification number and specific spreadsheets. In general our comments are:

1) Dow agrees with EPA concept of a complete and accurate database, however reviewing of a database of this size is a large undertaking and 60 days was not enough time to provide the level of review necessary to assure completeness and accuracy. Therefore, Dow suggests that the agency informally continue to accept comments, with full EPA review, from industry on the existing database thirty (30) additional days after the end of the comment period (until September 28, 2000). During this additional 30 days, Dow submit the missing data for one of its facilities impacted by the phase II rulemaking that is not included in the database and pages of reports supporting our findings that are inconsistent with what is currently in the database. Due to the shortness of the comment period, we could not provide all this data with these comments, but the data will be sent so it can be include the database.

Response: As discussed above in response to commenter No. 24 (the American Chemistry Council) in Section 2, the comment period will not be extended. This is primarily due to the extremely simple data base setup and structure to allow for easy review. However, EPA will do its best to fully consider all comments received after the comment period close date. Note that stakeholders will be able to review and comment on the data base again when the rule is proposed.

Dow I. D. Name: Symtet RAF EPA I. D. Number: CAD076528678 Facility Location: Pittsburg CA Data Submittal Date( s): July 5, 2000 (trial bum)

2) Dow is concerned that the database may be difficult to use for the purpose of setting standards if the data is not collected in a consistent manner. Due to the diversity of the units impacted by the potential rulemaking, there are different goals for the various performance tests. Therefore, the performance tests are performed in significantly different ways. We found several inconsistencies in how information was collected and inputted into the database. For example, the use of significant figures and exclusion of pemitted feedrate limits are two of these inconsistencies. It is important that well defined ground rules are established for the consistent collection and imputing of information into the database.

Response: Although we intended to collect on compliance test (i. e., trial burn or CoC testing) data for the Phase II data base, we acknowledge that some test conditions are actually risk burns where emissions may be representative of normal emissions rather than the worst case emissions of a compliance test. Further, data in a compliance test for one pollutant may represent worst case emissions (i. e, the emissions and other data were used to demonstrate compliance with an emission standard and establish operating limits) while data in that same test may represent normal emissions for another pollutant (e. g., emissions of the the pollutant may been measured even thought the source complied with Tier I feedrate limits for the pollutant and did not operating under worst case conditions for that pollutant). Accordingly, we have now classified the emissions data for each test condition as worst case versus normal.

We disagree with the commenter, however, that there are inconsistencies in how information was collected and incorporated in the data base. Procedures for collecting the data and incorporating the data into the data base are fully consistent and well defined in the report accompanying the release of the data base. Also, as discussed in response to commenter No. 24, permitted feedrate limits were, in fact, included in the data base; and the use of significant figures is consistent and sufficient within the accuracy of the overall data. Dow looks forward to working with EPA on the development of this Phase II Hazardous Waste Combustion rule and welcomes the opportunity to share it's knowledge and experience to help develop a workable and meaningful program. Please give us a call if you have any questions on these comments or if we can be of further assistance.

Sincerely,

Nathaniel R. Butler Paul Bork Environmental Associate Legal Department Environmental Services 517/ 636 4399 (517) 636 3711 517/ 638 9636 fax Comments of The Dow Chemical Company on F  2000  RC2A  FFFFF Corrections for Dow Allyns Point Facility (Phase II ID Number 729)

Source Description Spreadsheet:

Row 4  Tbe EPA ID Number is incorrect it should be CTDO01159730 not CTDO01159731 Corrections for Dow Pittsburgh Facility (Phase 11 ID Number 851)

Source Description Spreadsheet:

Row 22  The stack is listed as being 12 inches in diameter, however it is reduced to 8 inches two feet from the top.

Row 23  The stack height is listed incorrectly as 25.58 feet. The actual height is 74.5 feet above grade.

Stack Gas Emission Spreadsheet:

 Cell G8  This value was recorded incorrectly, 0.6 should be changed to 0.5.

 Cell I8  This value was recorded incorrectly, 0.6 should be changed to 0.5.

Cell GI 8  The wrong data cell was used in the formula to calculate this value. Cell G 1 4 the value for hexavalent chromium should have been used instead of cell G 1 2, the value of arsenic.  Cell II 8  The wrong data cell was used in the formula to calculate this value. Cell 114 the value for hexavalent chromium should have been used instead of cell II 2, the value of arsenic.

Cell E27  The wrong data cell was used in the formula to calculate this value. Cell E I I the value for chlorine should have been used instead of cell E20, the value of arsenic. Cell G27  The wrong data cell was used in the formula to calculate this value. Cell GI I the value for chlorine should have been used instead of cell G20, the value of arsenic.

Cell 127  The wrong data cell was used in the formula to calculate this value. Cell I the value for chlorine should have been used instead of cell I20, the value of arsenic.

The values in cells E32, G32 and I32 are incorrect and should be changed to 5.56E06, 5.78E 06 and 5.47E 06, respectively.

The values in cells E37, G37 and 137 are incorrect and should be changed to 1.33E05, 1.63E 05 and 1.91E 05, respectively.

The values in cells E7 1, G71 and 171 are incorrect and should be changed to 3.9 1 E06, 4.14E 06 and 3.96E 06, respectively.

The values in cells E76, G76 and 176 are incorrect and should be changed to 1. 19E05 1.36E 05 and 1. I 6E 05, respectively.

Cell B80  The units should be "dscftm" rather than "scftm"

The values in cells E93, G93 and 193 are incorrect and should be changed to 0.000014, 0.0000014, 0.000015, respectively.

Row 96 is a duplicate of row 93, values for chromium; row 96 needs to be deleted.

Row 103  The values for nickel are incorrect because of the extra row for chromium. After the deletion of the current row 96 the nickel values will move from row 97 to become the new row 96 which will correct the values in row 103.

The values in cells E130, G130, I130 and K130 are incorrect and should be changed to 1097, 1098, 1051 and 1082, respectively.

The values in cells E132, G132, I132 and K132 are incorrect and should be changed to 4.1, 3.9, 3.6 and 3.9, respectively.

The values in cells E133, G133, I133 and K133 are incorrect and should be changed to 157, 152, 145 and 151, respectively.

Feedstream Spreadsheet:

The barium emission value used in the formula to calculate the value in ce1 ID14 of 0.148 is incorrect and should be changed to 0.184.

The tier I and III constituents permitted feedrate limits should be added to this spreadsheet. PCDD/ PCDF Spreadsheet:

The value listed in cell J32 is incorrect and should be changed to 61.6.

Corrections for Dow Hanging Rock Facilitv (Phase II ID Number 730)

Feedstream Spreadsheet:

The tier I constituents permitted feedrate limits should be added to this spreadsheet.

Corrections for Torrance Facility (Phase II ID Number 733)

Source Description Spreadsheet:

The date of the certification of compliance test, August 1992, should be added to cell 29B.

Corrections for Freeport Facility (Phase 11 ID Number 786)

Feedstream Spreadsheet:

The values in cells D7, D78 and D99 are incorrect and should be changed to 5381.3, 4135.7 and 4918, respectively.

The tier I and III constituents permitted feedrate limits should be added to this spreadsheet.

Corrections for Freeport Facility (Phase 11 ID Number 788)

Feedstream Spreadsheet:

The units for density were incorrectly recorded in cell B I I 1 as lb./ gal and should be changed to g/ ml.

The values in cells D119, D123, D124, F116, F120 and F126 are incorrect and should be changed to 0.07, 0.2, 1.3, 0.8, 0.8 and 0.8, respectively The tier I and III constituents permitted feedrate limits should be added to this spreadsheet.

Corrections for Freeport Facility (Phase 11 ID Number 842)

Feedstream Spreadsheet:

The tier I and III constituents permitted feedrate limits should be added to this spreadsheet.

Corrections for Freeport Facilit y (Phase 11 ID Number 843) Feedstream Spreadsheet:

The value recorded in cell D77 for the feedrate of Heavy Oil is incorrect and should be changed to 3086.7.

The tier I constituents permitted feedrate limits should be added to this spreadsheet.

Corrections for Freeport Facility (Phase II ID Number 844)

Feedstream Spreadsheet:

The tier I constituents permitted feedrate limits should be added to this spreadsheet.

Corrections for Freeport Facility (Phase II ID Number 845)

Feedstream Spreadsheet:

The values recorded in cells D72 and F72 are incorrect and should be changed to 2476 and 2805, respectively.

The tier III constituents permitted feedrate limits should be added to this spreadsheet.

Corrections for Freeport Facility (Phase 11 ED Number 848)

Feedstream Spreadsheet:

The value recorded in cells D78 is in correct and should be changed to l541.

The tier III constituent permitted feedrate limit should be added to this spreadsheet.

Corrections for Freeport Facility (Phase 11 E[) Number 849)

Feedstream Spreadsheet:

The tier I and III constituents permitted feedrate limits should be added to this spreadsheet.

Corrections for Freeport Facility (Phase 11 IID Number 2017)

Stack Gas Emission Spreadsheet:

The value recorded in cell E7 is incorrect and should be 0.0062.

Feedstream Spreadsheet:

The values recorded in cells D8, DI3, D94 and E94 are in correct and should be changed to 27, 2840, 2015 and 1524, respectively.

The tier I and III constituents permitted feedrate limits should be added to this spreadsheet.

Corrections for Freeport Facility (Phase 11 ID Number 2018)

Feedstream Spreadsheet:

The values recorded in cells D29 and D43 are incorrect and should be changed to 34.9 and 0.22, respectively.

The tier I and III constituents permitted feedrate limits should be added to this spreadsheet.

Corrections for Freeport Facility (Phase 11 ID Number 2020)

Feedstream Spreadsheet:

The tier III constituent permitted feedrate limits should be added to this spreadsheet.

Response Responses to these specific data base issues are contained in the attached data base correction summary Table 3. We agree with most of the suggested changes. Note that Tier I and III feedrate limits have been added where available.

5.19 General Electric (Phase II ID # 766)

GE (20)

This e mail contains a comment from General Electric Company (" GE") on EPA's June 27, 2000 "Notice of data availability for future Phase 11 combustion rulemaking" published at 65 Federal Register 39,581. This e mail supplements the written comments dated August 21, 2000 that GE has already filed. In the "source" worksheet of workbook 766. xls (for the GE Plastics facility in Selkirk, NY), the "Permifting Status" is shown as "Tier I A for metals and chlorine". This is incorrect. The limits for metals and chlorine are adjusted Tier I feed rate screening limits established pursuant to 40 CFR 266.106( e). Thus, this entry should be changed to read "Adjusted Tier I for all metals and chlorine".

Please contact either Stephen Capone (Manager, Air Regulatory Programs for GE Plastics, 413 448 7609) or me (812 831 4688) if you have any questions. Thank you.

Regards, Alphonse McMahon Counsel EHS Programs, GE Plastics al. mcmahon@ gep. ge. com Response No change is made. We do not understand what is wrong with the NODA data base entry. Tier IA implies that adjusted Tier I feedrate limits are used to set metals and chlorine limits. This is what is suggested as the change.

5.20 DSM (Phase II # 754, 756)

DSM Elastomers Americas, DSM Copolymer, Inc (21)

DSM Elastomers Americas is pleased to provide the following comments on this NODA for Phase 11 MACT combustion rulemaking for hazardous waste boilers and industrial furnaces:

The database containing our 1997 risk bum results does not illustrate natural gas data that we submitted to the United States Environmental Protection Agency Region VI, AR/ LA RCRA Permits Section (6PD A). We conducted a second test on our hazardous waste boiler using just natural gas tested under USEPA risk bum protocol but without supplemental hazardous waste fuel. This test showed no appreciable difference in results between the two bums and shows an excellent baseline for comparison between firing media. We feel that the Agency should include this data because it has been considered in determination of permitted conditions for our Louisiana facility and it shows expected results in the stack effluent in both tests by Compounds of Potential Concern (COPCs).

In our hazardous waste boiler operations, we utilize a 90/ 10 ratio of natural gas to hazardous waste fuel rate. We feel that scaling emissions detected in the 1997 risk bum according to the natural gas to hazardous waste ratio should be strongly considered by the Agency. The attached document is Section 3.10 of our Risk Bum Final Report submitted to the United States Environmental Protection Agency Region VI, AR/ LA RCRA Permits Section (6PD A). This section demonstrates a comparison between results from burning hazardous waste versus buming just natural gas. The natural gas data is contained under the Baseline Data columns. This comparison plus the feed ratios should be considered strongly by the Agency during permit determinations.

Response: Test data from burning natural gas only is not of direct interest in this rulemaking, which concerns the performance of systems burning hazardous wastes. We are not sure how it could be used or is appropriate for determining the performance of boilers burning hazardous wastes. Also, we are not sure how scaling emissions from natural gas and hazardous waste is appropriate, particularly given that emissions from hazardous waste is directly available.

The BIF facilities in Louisiana are currently being evaluated by the United States Environmental Protection Agency Region VI for unacceptable risk associated with exposure to emissions from hazardous waste boilers and industrial furnaces. Those facilities who chose to assume Tier I emission limits for BIF metals where detection limits have not be low enough (either by testing or by the Tier I emission limit) to meet the risk assessment protocol values. For those non detect metals in the waste stream the reported method detection limit from the laboratory is being calculated into a reliable detection limit by USEPA Region VI and used in the analysis. For certain non detect metals this practice is causing unacceptable risk in the final analysis. Since, the Phase I HWCMACT standards were based upon a risk assessment analysis DSM Elastomers Americas feels that the Agency needs to adequately address the detection limit problem found with non detect metals in the waste feed analysis before developing emission standards for boilers and industrial furnaces that balance science with safety of the neighbors surrounding our plants.

Response: Procedures for handling non detect feedrate measurements in assessing the protectiveness of the MACT standards will be given consideration at a later date. We currently plan to consider stack gas emissions measurements assuming that non detects are present at one half of the reported detection limit. If feedrate measurements are used to assess the protectiveness of the MACT standards, procedures used for handling non detects will be presented for review and comment in the proposed rule..

Thank you for allowing us the opportunity to provide comments on the data that will be used for developing MACT emissions standards for hazardous waste boilers and industrial furnaces. If you have any questions please give me a call at (225) 267 3466.

5.21 Union Carbide (Phase II # 753, 907, 908, 910)

Union Carbide Corporation (22)

Union Carbide Corporation (UCC) is pleased to submit comments on the Environmental Protection Agency's (EPA) June 27, 2000 notice of data availability for future Phase 11 combustion rulemaking.

UCC is a global chemical manufacturer and has a number of facilities in the United States that will be impacted by this future combustion rule. As such, we are very interested in seeing the Agency produce a sound facility database to be used for rulemaking. We have attached a series of comments on data tables presented in the NODA, and are also submitting corrected copies of spreadsheets containing data on UCC's four boilers subject to these rules. One boiler, No. 53 at our Texas City, TX plant, is new and presently undergoing trial burn tests. We will be submitting a copy of the draft trial burn report in a separate mailing.

If there are any questions on these comments, please contact me at 504 783 4568 or Mr. W. Y. Wang at 304 747 5279.

Attachments (6) Very truly yours,

P. F. Normand, P. E. Waste Issue Manager Union Carbide Corporation ATTACHMENT I RESPONSE TO EPA REQUEST FOR COMMENTS ON ACCURACY AND COMPLETENESS OF THE DATABASE UCC's comment is mainly for deletion of two old boilers and for inclusion of one new boiler:

1. Phase 11 Database Table 1. Universe of Phase 11 HWC Sources (Listed by Phase 11 ID No.):

UCC requests deletion of Phase 11 ID No. 907 boiler. This Boiler 15 is no Ionger in service and has been closed. See others below.

UCC requests inclusion in database and a Phase II ID No. for a new watertube boiler (Unit ID Boiler 53) at the Union Carbide Corporation Texas City site (EPA ID No. TXDOOO461533).

2. Phase 11 Database Table 2. Universe of Phase 11 HWC Sources (Listed by Facility Name):

UCC requests deletion of Phase 11 ID No. 907 boiler. This Boiler 15 is no longer in service and has been closed.

UCC requests inclusion in database and a Phase 11 ID No. for a new watertube boiler (Unit ID Boiler 53) at the Union Carbide Corporation Texas City site (EPA ID No. TXDOOO461533).

3. Phase 11 Database Table 3. Universe of Phase 11 HWC Sources (Listed by General Source Type):

UCC requests deletion of Phase 11 ID No. 907 boiler under "steam boilers". This Boiler 15 is no longer in service and has been closed.

UCC requests inclusion in database and a Phase 11 ID No. for a new watertube boiler (Unit ID Boiler 53) at the Union Carbide Corporation Texas City site (EPA ID No. TXDOOO461533).

4. Phase li Database Table 4. "SisteC '( Data in Lieu) Units (Listed by Phase ll ID No.):

UCC requests deletion of Phase 11 ID No. 907 boiler. This Boiler 15 is no longer is no longer in service and has been closed.

UCC requests inclusion in database and a Phase 11 ID No. for a new watertube boiler (Unit ID Boiler 53) at the Union Carbide Corporation Texas City site (EPA ID No. TXDOOO461533). There is no sister unit for Boiler 53.

UCC requests deletion of Boiler 4 under Phase l[ ID No. 910 boiler. Boiler 4 is no longer for hazardous waste service. 5. Phase 11 Database Table 5. Phase 11 BIF Population Characterization:

UCC requests revision of Table 5 to reflect changes of UCC and/ or non UCC boiler data. 6.

Phase 11 Database Table 6. Boilers:

UCC requests deletion of Phase 11 ID No. 907 boiler. This Boiler 15 is no longer in service and has been closed.

UCC requests inclusion in database and a Phase 11 ID No. for a new watertube boiler (Unit ID Boiler 53) at the Union Carbide Corporation Texas City site (EPA ID No. TXDOOO461533). This new boiler uses fuel gas as auxiliary fuel.

Under the Phase 11 ID 908 boiler, UCC requests the change of auxiliary fuel from "Coal (pulverized)" to 'Coal (pulverized)/ Natural gas".

7. Phase 11 Database Data and Information File for Individual Sources on Source Description Sheet, Emission Data Sheet, Feed Stream Data Sheet, Process Data Sheet, PCDD/ PCDF Sheet, Emissions and Feedrate Data Summary Sheet, and Source Description Summary Sheet:

UCC requests deletion of Phase 11 ID No. 907 boiler. This Boiler 15 is no longer for hazardous waste service.

UCC requests deletion of Boiler 4 under Phase ll iD No. 910 boiler. Boiler 4 was listed as a sister unit for Boiler 5. Boiler 4 is no longer for hazardous waste service.

UCC requests inclusion in database and a Phase II ID No. for a new watertube boiler (Unit ID Boiler 53) at the Union Carbide Corporation Texas City site (EPA ID No. TXDOOO461533). The complete COC and trial burn data has just become available in August 2000. Data and information file for this new boiler is shown in the attachment in the similar format as those for the other UCC boilers.

UCC requests minor revisions on the Phase II ID No. 753, 908, and 910 boilers, as shown in the attached files.

** Remaining attachments are copies of excel file spreadsheets and new trial burn emissions test report from a new hazardous waste burning boiler at the Union Carbide Texas City TX plant.**

Response The new facility test report for the new facility just starting to burn hazardous waste has been entered under a new facility ID No. 2021.

Unit ID No. 907 has been reclassified as no longer burning waste. The sister unit Boiler No. 4 under ID No. 920 has been removed (Boiler No. 4 is no longer burning hazardous wastes).

Other minor changes were made as noted or discovered in the supplied revised attached files.

5.22 Rohm and Haas (Phase II Unit ID Nos. 740, 741)

Rohm and Haas (23)

Provided comments to unit ID Nos. 740 and 741 on modified Excel spreadsheets Response EPA has reviewed the requested data base edits. Responses to these requested changes or additions are documented in Table 3.

5.23 Solutia (Phase II ID No. 232)

Solutia Inc. (L1)

Enclosed please find an original plus two copies of our comments on the Notice of Data Availability (NODA) published by EPA on 6 27 2000 in the Federal Register. Our principal comment is that a portion of the reported Dioxin/ Furan stack emissions from our 1997 BIF Trial Bum appear to be incorrectly reported in the EPA data base and we respectfully request that the EPA data base be corrected. The total PCDD/ PCDF Toxic Equivalent (TEQ) values appear to be correctly reported, while the total PCDD/ PCDF values appear to be in error as follows:

PCDD/ PCDF Trial Bum PCDD/ PCDF EPA BIF NESHAP Solutia 1997 Trial Bum Test Condition Reporting Basis Average Condition Data Average Condition Data 1 Total TEQ ng/ dscm 0.0092 0.0092 @7% 02 1 Total ng/ dscm @7% 02 0.0846 0.136 2 Total TEQ ng/ dscm 0.0016 0.0016 @7% 02 2 Total ng/ dscm @7% 02 1 0.0294 1 0.0350 9 6 2000 The attached Tables 4 36, 4 38, 4 39, & 4 40 are copies of the Solutia reported PCDDIPCDF Trial Bum Results for Test Condition 1. The attached Tables 4 37, 4 41, 4 42, & 4 43 are copies of the Solutia reported PCDD/ PCDF Trial Bum Results for Test Condition 2. If you have any questions or need any additional information, please contact me at 281 228 4762.

Sincerely,

Thomas M. Moran, P. E. Senior Environmental Specialist Enclosures: Solutia Trial Bum Report Tables: 4 36, 4 38, 4 39, 4 40, 4 37, 4 41, 4 42, & 4 43.

Response No changes are made. The total PCDD/ PCDF values as reported and calculated by EPA in the NODA are correct and based on handling non detect measurements (those at the detection limit) at one half of the detection limit. The total PCDD/ PCDF levels shown by Solutia in the comment above are based on the use of the full detection limit (as opposed to the TEQ values, which are based on use of one half of the detection limit  this is why the commenters TEQ values are identical to the NODA values  i. e., both were based on the use of one half of the detection limit).

5.23 Eastman L2 (Eastman)

Unit 717 is no longer burning hazardous waste.

Response This information has been added to the data base. Table 1. List of NODA Data Base Commenters and Identification Numbers Comment Submittal Docket ID No. Commenter Name Phase II ID No. Impacted 1 Arch Chemicals, Inc. 1008 2 Merck & Co., Inc. 780, 781 3 Exxon Chemical Co. 822 4 Westvaco 818 5 General Electric Plastics Co. 764, 765, 766 6 Eastman Chemical Company, Texas Operations 854 7 Mallinckrodt, Inc. 778, 1000 8 DuPont/ Dow Elastomers 853 9 Merck & Co., Inc. 780, 781 10 Celanese Ltd., Bay City 721 (1013, 1014, 1018 no comments received)

11 Eastman Chemical Company (Kingsport, Tennessee) 717, 719, 1011, 1012 12 Celenese Ltd., Clear Lake Plant 720 13 Georgia Gulf 855, 2000 14 Lyondell Chemical 1002, 1003, 1004 15 Reilly Industries 735, 737, 738 16 Ticona Polymers, Inc. 1018 17 Rubicon Inc. 812, 813, 814, 815 18 Equistar Chemicals, LP 774 19 Dow 729, 851, 730, 733, 786, 788, 842, 843, 844, 845, 848, 849, 2017, 2018, 2020 20 General Electric 764, 765, 766 21 DSM 754, 756 22 Union Carbide 753, 907, 908, 910, 2021 23 Rohm and Haas Company 740, 741 24 American Chemistry Council No specific ones L1 Solutia 232 L2 Eastman 717 O1 Sun O2 Rhodia Table 2. Universe of Phase II Sources and Status of Comments Received Nothing Comments from company only Received specific comments on unit Phase II ID No. Facility Name City State EPA ID No. Comb Type APCS y 2006 3V Inc. Georgetown SC SCD980500052 Firetube boiler None y 2007 Air Products Manufacturing Corp. Wichita KS KSD007237746 Boiler None y 763 Albermarle Corp. Orangeburg SC SCD043384072 Boiler FF y 828 Angus Chemical Company Sterlington LA LAD020597597 Watertube boiler None y 1008 Arch Chemicals, Inc. (Olin) Beaumont TX TXD008097487 Sulfuric Acid Recovery Furnace WHB/ QT/ DT/ SO3CON y 1002 ARCO Chemical Co. (Lyondell) Channelview TX TXD083472266 Boiler None y 1003 ARCO Chemical Co. (Lyondell) Channelview TX TXD083472266 Hot oil heater None y 1004 ARCO Chemical Co. (Lyondell) Channelview TX TXD083472266 Hot oil heater None y 1017 Aristech Chemical Corp. Pasadena TX TXD980808778 Boiler None y 911 Aristech Chemical Corporation Haverhill OH OHD005108477 Watertube boiler None y 912 Aristech Chemical Corporation Haverhill OH OHD005108477 Watertube boiler None y 834 BASF Geismar LA LAD040776809 Combustor/ waste heat boiler None y 835 BASF Geismar LA LAD040776809 Watertube boiler None y 836 BASF Geismar LA LAD040776809 Watertube boiler None y 833 BASF Corporation Freeport TX TXD008081697 Boiler None y 1016 BASF Corporation Beaumont TX TXD067261412 ? None y 840 Bayer (Monsanto Co. Port Plastic Plant) Addyston OH OHD004233003 Watertube boiler None y 785 Borden Chemicals and Plastics (BCP) Geismar LA LAD003913449 Halogen Acid Furnace GC/ HE/ QC/ AT/ WS y 1013 Celanese Pampa TX TXD007376700 Watertube boiler FF y 1014 Celanese Pampa TX TXD007376700 Watertube boiler FF y 721 Celanese Ltd Bay City TX TXD026040709 Watertube boiler None y 1018 Celanese Ltd Bishop TX TXD008113441 Watertube boiler None y 720 Celanese Ltd., Chemical Group Clear Lake Plant Pasadena TX TXD078432457 Boiler None y 901 Diversified Scientific Services, Inc. Kingston TN TND982109142 Firetube boiler SD/ FF/ PBS/ RH/ HEPA y 733 Dow Chemical Co. Torrance CA CAD009547050 Process heater None y 2001 Dow Chemical Co. Plaquemine LA LAD008187080 Firetube boiler HClABS/ CWS y 2002 Dow Chemical Co. Plaquemine LA LAD008187080 Firetube boiler Q/ HClABS/ CWS y 2003 Dow Chemical Co. Plaquemine LA LAD008187080 Firetube boiler Q/ HClABS/ CWS y 730 Dow Chemical Co. Hanging Rock Plant Ironton OH OHD039128913 Process heater None y 786 Dow Chemical Company Freeport TX TXD008092793 Halogen Acid Furnace DQ/ HCLABS/ VS/ CLW y 788 Dow Chemical Company Freeport TX TXD008092793 Halogen Acid Furnace MGCLREC/ VS/ SEP/ D y 842 Dow Chemical Company Freeport TX TXD008092793 Halogen Acid Furnace WHB/ HCLABS/ WS y 843 Dow Chemical Company Freeport TX TXD008092793 Watertube boiler None y 844 Dow Chemical Company Freeport TX TXD008092793 Halogen Acid Furnace WHB/ HCLABS/ WS y 845 Dow Chemical Company Freeport TX TXD008092793 Halogen Acid Furnace WHB/ Q/ HCLABS/ VS/

y 848 Dow Chemical Company Freeport TX TXD008092793 Halogen Acid Furnace WHB/ HClABS/ CWS y 849 Dow Chemical Company Freeport TX TXD008092793 Firetube boiler VS/ WS y 2017 Dow Chemical Company Freeport TX TXD008092793 Halogen Acid Furnace WHB/ Q/ HClABS/ VE/ C y 2018 Dow Chemical Company Freeport TX TXD008092793 Halogen Acid Furnace WHB/ VS/ Q/ HCLABS/ V y 2020 Dow Chemical Company Freeport TX TXD008092793 Halogen Acid Furnace WHB/ VS/ WS y 851 The Dow Chemical Company Pittsburg CA CAD076528678 Halogen Acid Furnace Q/ HClABS/ WS Page 1 of 6 Table 2. Universe of Phase II Sources and Status of Comments Received Nothing Comments from company only Received specific comments on unit Phase II ID No. Facility Name City State EPA ID No. Comb Type APCS y 729 Dow Chemical U. S. A. Allyn's Point Facility Gales Ferry CT CTD001159731 Process heater None y 754 DSM Chemicals North America, Inc.. Augusta GA GAD051011609 Boiler None y 756 DSM Copolymer Inc. Addis LA LAD059130831 Watertube boiler None y 853 Dupont Dow Elastomers LaPlace LA LAD001890367 Halogen Acid Furnace WQ/ 3STGHClABS/ S/ C y 2013 E. I. Du Pont De Nemours & Company, Inc. Victoria TX TXD008123317 Boiler ?

y 2016 E. I. Du Pont De Nemours & Company, Inc. Victoria TX TXD008123317 Boiler ?

y 2012 E. I. Du Pont Nemours & Company, Inc. Victoria TX TXD008123317 Boiler ?

y 759 E. I. duPont de Nemours & Co., Inc. Orange TX TXD008123317 Boiler ?

y 760 E. I. duPont de Nemours & Co., Inc. Orange TX TXD008123317 Boiler None y 761 E. I. duPont de Nemours & Co., Inc. Orange TX TXD008123317 Boiler None y 717 Eastman Chemical Company Kingsport TN TND003376928 Watertube boiler (suspension fired) SDA/ ESP y 1009 Eastman Chemicals Co.  Arkansas Eastman Div Batesville AR ARD089234884 Watertube boiler (stoker) ESP y 719 Eastman Chemicals Co.  Tennessee Eastman Div Kingsport TN TND003376928 Watertube boiler (spreader stoker) ESP y 1011 Eastman Chemicals Co.  Tennessee Eastman Div Kingsport TN TND003376928 Watertube boiler (spreader stoker) ESP y 1012 Eastman Chemicals Co.  Tennessee Eastman Div Kingsport TN TND003376928 Watertube boiler (spreader stoker) ESP y 854 Texas Eastman Division Eastman Chemical CompanLongview TX TXD007330202 Halogen Acid Furnace QT/ ABS/ WS y 2014 Environmental Purification Industries Toledo OH OHD986983237 Boiler None y 2015 Environmental Purification Industries Toledo OH OHD986983237 Hot oil heater None y 774 Equistar Chemicals, LP  Channelview Complex Channelview TX TXD058275769 Watertube boiler None y 822 Exxon Chemical Co. (no longer burns haz waste) Baton Rouge LA LAD000778381 Boiler None y 811 Fina Oil & Chemical Co. La Porte TX TXD086981172 Watertube boiler VS y 764 GE Plastics, Mt. Vernon IN Facility Mount Vernon IN IND006376362 Watertube boiler None y 765 GE Plastics, Mt. Vernon IN Facility Mount Vernon IN IND006376362 Watertube boiler None y 766 General Electric Plastics Selkirk NY NYD06683023 Hot oil heater None y 855 Georgia Gulf Plaquemine LA LAD057117434 Halogen Acid Furnace WHB/ 4STGHClABS/ C y 2000 Georgia Gulf Corp. Plaquemine LA LAD057117434 Watertube boiler None y 1015 Georgia Gulf Corporation Pasadena TX TXD093565653 Hot oil heater None y 767 Goodyear Tire and Rubber Company Beaumont TX TXD008077190 Watertube boiler None y 820 Hercules Inc.  Jefferson Plant West Elizabeth PA PAD000606285 Watertube boiler None y 821 Hercules Inc.  Jefferson Plant West Elizabeth PA PAD000606285 Watertube boiler None y 1005 Huntsman Corp. (formerly Texaco) Port Neches TX TXD008076846 Boiler None y 1006 Huntsman Corp. (formerly Texaco) Port Neches TX TXD000201202 Watertube package boiler None y 1007 Huntsman Polymers Odessa TX TXD980626014 Boiler None y 771 Kalama Chemical (BF Goodrich) Kalama WA WAD092899574 Watertube boiler FF y 772 Lonza, Inc. Pasadena TX TXD084970169 Boiler None y 1001 Lonza, Inc. Pasadena TX TXD084970169 Boiler None y 778 Mallinckrodt Inc. Raleigh NC NCD042091975 Watertube boiler None y 1000 Mallinckrodt Inc. Raleigh NC NCD042091975 Watertube boiler None y 780 Merck & Co., Inc Rahway NJ NJD001317064 Watertube boiler None y 781 Merck & Co., Inc Rahway NJ NJD001317064 Watertube boiler None y 724 Merichem Company Houston TX TXD008106999 Boiler Q/ ME Page 2 of 6 Table 2. Universe of Phase II Sources and Status of Comments Received Nothing Comments from company only Received specific comments on unit Phase II ID No. Facility Name City State EPA ID No. Comb Type APCS y 776 Monsanto (Nutrasweet Kelco Co.) Augusta GA GAD981237118 Firetube boiler QC/ WS y 777 Monsanto (Nutrasweet Kelco Co.) Augusta GA GAD981237118 Firetube boiler QC/ WS y 735 Reilly Industries, Inc. Indianapolis IN IND000807107 Watertube boiler None y 737 Reilly Industries, Inc. Indianapolis IN IND000807107 Watertube boiler None y 738 Reilly Industries, Inc. Indianapolis IN IND000807107 Watertube boiler None y* 2004 Rhodia (formerly Rhone Poulenc Basic Chemical CoBaton Rouge LA LAD008161234 Sulfur Acid Recovery Unit Wet ESP y* 2019 Rhodia (formerly Rhone Poulenc Basic Chemical CoBaton Rouge LA LAD008161234 Sulfur Acid Recovery Unit WESP y* 1010 Rhodia (Rhone Poulenc) Houston TX TXD008099079 Sulfuric Acid Regeneration Furnace WHB/ QT/ CC/ WESP/ D y* 856 Rhodia Inc. Hammond IN IND001859032 Sulfuric Acid Recovery Furnace WHB/ QT/ GC/ WESP/ S y 819 Rhone Poulenc AG Company Charleston WV WVD005005509 Watertube boiler ESP y 740 Rohm and Haas Deer Park TX TXD065096273 Watertube boiler None y 739 Rohm and Haas Company Bristol PA PAD002292068 Watertube boiler None y 741 Rohm and Haas Company Knoxville TN KYD006390017 Watertube boiler None y 812 Rubicon, Inc Geismar LA LAD008213191 Boiler Q/ WS y 814 Rubicon, Inc Geismar LA LAD008213191 Boiler None y 815 Rubicon, Inc Geismar LA LAD008213191 Boiler None y 813 Rubicon, Inc. Geismar LA LAD008213191 Boiler FF y 743 Schenectady International Freeport TX TXD010797389 Boiler None y 744 Shell Deer Park Refining Company Deer Park TX TXD067285793 Watertube boiler None y 745 Shell Deer Park Refining Company Deer Park TX TXD067285793 Watertube boiler None y 232 Solutia (Chocolate Bayou Plant) Alvin TX TXD001700806 Boiler None y 746 Sterling Chemicals, Inc. Texas City TX TXD008079527 Firetube boiler None y* 2008 Sun Company, Inc. (R & M) Frankford Plant Philadelphia PA PAD002312791 Watertube boiler None y 753 Union Carbide Corp. Hahnville LA LAD041581422 Watertube boiler None y 907 Union Carbide Corporation South Charleston WV WVD005005483 Watertube boiler ESP y 908 Union Carbide Corporation South Charleston WV WVD005005483 Watertube boiler ESP y 910 Union Carbide Corporation Texas City TX TXD000461533 Watertube boiler None y 769 Velsicol Chemical Corp. Chestertown MD MDD001890060 Firetube boiler None y 2009 Velsicol Chemical Corp. Chestertown MD MDD001890060 Hot oil system process heater None y 2010 Velsicol Chemical Corp. Chestertown MD MDD001890060 Hot Oil System Process Heater None y 2011 Velsicol Chemical Corp. Chestertown MD MDD001890060 Hot Oil System Process Heater None y 2005 Vulcan Materials Co. Geismar LA LAD092681824 Halogen Acid Furnace WHB/ QT/ WS y 818 Westvaco DeRidder LA LAD010390599 Watertube boilers ESP Page 3 of 6 Table 2. Universe of Phase II Sources and Status of Comments Received Phase II ID No. 2006 2007 763 828 1008 1002 1003 1004 1017 911 912 834 835 836 833 1016 840 785 1013 1014 721 1018 720 901 733 2001 2002 2003 730 786 788 842 843 844 845 848 849 2017 2018 2020 851 Waste Type Aux Fuel Unit ID Name/ No. Sister Units Capacity (MMBtu/ hr)

Liq Natural gas, No. 2 fuel oil Unit No. 1 (or No. 2?) None 34.0 Liq Natural gas COEN boiler None 12.4 Liq ? Unit No. 4 None 25.0 Liq Natural gas, hydrogen No. 7 Boiler No. 4 Boiler 150.0 Liq Natural gas and process gas Sulfuric acid regeneration furnace None 200.0 Liq Natural gas, propane purge Utility Boiler 3 Utility Boilers 1 and 2 ?

Liq Natural gas F 57180 Hot Oil Heater None 138.0 Liq Natural gas, process vapors F 65630 Hot Oil Heater None 138.0 Liq Natural gas Boiler F 8 None 100.0 Liq Natural gas or fuel oil Unit 2001 UA Units UB, UC (2 other identical units) 190.0 Liq Natural gas or No. 6 fuel oil Unit 2001 UE None 182.0 Liq Natural gas Amines None 15.0 Liq Natural gas No. 3 Boiler None 285.0 Liq Natural gas No. 6 Boiler None 300.0 Liq ? Neol Boiler None 48.9 Liq ? WOD K541 None 12.8 Liq Natural gas Boiler No. 4 None 48.0 Liq ? VCR Process Unit None 30.0 Liq Coal (pulverized), still solids Boiler No. 9 None 740.0 Liq Coal (pulverized), still solids Boiler No. 10 None 1000.0 Liq Natural gas Boiler No. 4 Boiler No. 5 408.8 Liq Natural gas Boiler No. 16 None 63.1 Liq Natural gas MH5A None 50.0 Liq Propane DSSI Mixed Waste Industrial Boiler System None 15.0 Liq Natural gas U 305 U 304 (identical) 9.8 Liq Natural gas F 410 F 420 identical unit 40.0 Liq Natural gas R 4 None 45.0 Liq Natural gas R 750 None 15.0 Liq Natural gas Unit R 1 Unit R 3 identical unit 9.0 Liq Natural gas Unit R 30 None 31.0 Liq Natural gas B 824 None 88.0 Liq Natural gas Unit FTB 400 None 28.0 Liq Natural gas B 902 B 901, B 903 229.0 Liq Natural gas F 2AB None 35.0 Liq Natural gas F 210 None 50.2 Liq Natural gas F 11 None 24.0 Liq Natural gas F 820AB None 32.0 Liq Natural gas Unit FTB 401 Unit FTB 402 42.0 Liq Natural gas Unit FTB 603 None 50.2 Liq Natural gas F 2820 None 40.0 Liq Natural gas MS HAF None 5. 2 Page 4 of 6 Table 2. Universe of Phase II Sources and Status of Comments Received Phase II ID No. 729 754 756 853 2013 2016 2012 759 760 761 717 1009 719 1011 1012 854 2014 2015 774 822 811 764 765 766 855 2000 1015 767 820 821 1005 1006 1007 771 772 1001 778 1000 780 781 724 Waste Type Aux Fuel Unit ID Name/ No. Sister Units Capacity (MMBtu/ hr)

Liq and solid No. 2 fuel oil Boiler Unit A None 9. 0 Liq Natural gas H 002 Boiler H 2002 Boiler 162.0 Liq Natural gas No. 3 boiler None 268.0 Liq Natural gas HCl Recovery Unit None 48.0 Liq ? Boiler Nos. 3 & 4 None 1000.0 Liq ? Boiler No. 1 None 400.0 Liq Natural gas Boiler No. 7 Boiler No. 8 250.0 Liq Natural gas Boiler No. 7 Boiler No. 5 300.0 Liq Natural gas Boiler No. 8 None 350.0 Liq Natural gas ADN North ADN South 600.0 Liq Coal (pulverized) Unit No. 30 (HWTU 5, at Site B 325) None 780.0 Liq Coal Boiler No. 3 Boiler No. 2 100.0 Liq, sludge Coal Boiler No. 24 Boiler No. 23 501.0 Liq, sludge Coal Boiler No. 20 Boiler Nos. 18 and 19 196.0 Liq Coal, biosludge Boiler No. 22 Boiler No. 21 216.0 Liq Natural gas RCRA BIF Unit (Halogen Acid Furnace) None 30.0 Vapors Natural gas WHB Unit No. 1 None 8. 0 Vapor Natural gas WHB Unit No. 2 None 8. 0 Liq Natural gas Boiler No. 3 None 83.6 Liq Natural gas C Boiler D Boiler identical 50.0 Liq Natural gas Train A Waste Heat Boiler Train B Waste Heat Boiler 70.0 Liq Natural gas Boiler H530A (Unit 1) None 75.0 Liq Natural gas Boiler H530B (Unit 2) None 75.0 Liq Natural gas A/ P Hot Oil Heater None 180.0 Liq Natural gas IN 662 None 70.0 Liq, tar Natural gas, fuel oil Nebraska Boiler None 190.0 ? Natural gas Hot Oil Heater No. 1 None 250.0 Liq Natural gas Boiler B 103 Boilers B 101, B 102, B 104, B 105 (a 100.0 Liq Fuel oil Boiler No. 3 Boiler No. 4 30.0 Liq Fuel oil Boiler No. 5 None 40.0 Liq Fuel gas, sponge oil Boiler # 1 (6 BB 1) Boiler # 2 (6 BB 2) 549.0 Liq Natural gas and process vapors PO/ MTBE steam generator # 1 (H K2 001) Unit # 2 (H K2 002)  identical 225.0 Liq Natural gas C Boiler None 300.0 Liq Natural gas U 3 Boiler None 50.0 Liq Natural gas Boiler B 4001B B 4001A  identical unit 39.0 Liq Natural gas Boiler B 4001C None 39.0 Liq Natural gas Boiler No. 1 None 19.0 Liq Natural gas Boiler No. 2 None 30.0 Liq Natural gas Boiler No. 7 None 134.0 Liq Natural gas Boiler No. 8 None 156.0 Liq Natural gas Boiler No. 4 None 68.0 Page 5 of 6 Table 2. Universe of Phase II Sources and Status of Comments Received Phase II ID No. 776 777 735 737 738 2004 2019 1010 856 819 740 739 741 812 814 815 813 743 744 745 232 746 2008 753 907 908 910 769 2009 2010 2011 2005 818 Waste Type Aux Fuel Unit ID Name/ No. Sister Units Capacity (MMBtu/ hr)

Liq Natural gas Boiler 1  WHRU 1 None 66.0 Liq Natural gas Boiler 2  WHRU 2 None 26.0 Liq Natural gas Boiler 70K None 92.0 Liq Natural gas 30K None 39.3 Liq Natural gas Boiler 28K None 36.8 Liq Natural gas Unit 1 None 140.0 Liq Natural gas Unit 2 ? 250.0 Liq, sludge Natural gas Regeneration Unit No. 2 None 200.0 Liq Natural gas Sulfuric Acid Recovery Unit No. 4 None 250.0 Liq Natural gas Boiler No. 3 Boiler No. 4 1131.2 Liq Natural and process gas HT 1 Thermal Oxidizer None 335.0 Liq No. 6 fuel oil, natural gas Boiler No. 7 Boiler Nos. 6 and 8 120.0 Liq Natural gas, No. 2 fuel oil Unit No. 100 None 248.0 Liq Natural gas TDI boiler None 30.0 Liq Natural gas DPA I Superheater None 20.0 Liq Natural gas DPA II superheater None 20.0 Liq None Aniline II boiler None 40.0 ? Natural Gas B 503 None 30.0 Liq Natural gas F UT 100 F UT 110 600.0 Liq Natural gas F UT 130 None 600.0 Liq Natural gas; vent gas (propane) Boiler 30H5 Boiler 31H4 (identical) 600.0 Liq Natural gas and process gas Waste Oxidation Boiler A None 180.0 Liq Natural gas Boiler No. 2 Boiler No. 1 (Phase II ID No. 900) 200.0 Liq Gas/ oil Boiler 31 None 241.0 Liq Coal (pulverized) Boiler 15 None 204.0 Liq Coal (pulverized) Boiler 25 None 323.0 Liq Fuel gas Boiler 5 Boiler 4 (identical) 200.0 Liq No. 6 fuel oil Unit No. 4 (Cleaver Brooks Boiler) None Liq No. 6 fuel oil Hot Oil System Unit No. 1 None 10.0 Liq No. 6 fuel oil Hot Oil System Unit No. 2 None 14.0 Liq No. 6 fuel oil Hot Oil System Unit No. 3 None 14.0 Liq ? F 1 Unit None 20.0 Liq, residues Tall oil pitch and heads fuel, fuel Boilers No. 2 and 3 (common ESP and stack) None 86.0 Page 6 of 6 Table 3. Responses to Requests for Data Base Changes Comment ID No. Phase II ID No. Commentators Requested Action NODA Data Base Value Action Taken 1 1008 Supplemental fuel = natural gas. No process gas fired. Supplemental fuel = natural gas and process gas Modified as requested 1 1008C1 Total spike feed rate = 305 lb/ hr 226.4 lb/ hr Verified that data base value was incorrect; recalculated at 298.9 lb/ hr;

used commenters value.

1 1008C1 Additional feed stream data provided: Sulfur firing rate = 45. 7 MMBtu/ hr. Estimated firing rate = 145 MMBtu/ hr No data for sulfur firing rate.

Estimated total firing rate = 187.1 MM Btu/ hour Added as requested 1 1008 New and more BIF Tier I and Tier III feedrate limits BIF feed rate limits: Tier I: Ba =

284,407 g/ hr, Ag = 17,055 g/ hr; No feed limits available for the Tier III metals Added and modified as requested 2 780 Additional Stack Characteristics provided:

Diameter = 10 ft, Height = 235 ft , Gas Velocity = 5. 8 ft/ sec. Added data 2 781 Additional Stack Characteristics provided:

Diameter = 10 ft, Height = 235 ft, Gas Velocity = 5.8 ft/ sec. Added data 2 781C2 Testing Dates = October 18 19, 1999 October 19 20, 1999 Modified as requested 3 822 No longer burning hazardous waste as of May 17, 1999 Currently burning hazardous waste Marked as no longer burning hazardous waste 4 818 Capacity = 65 MMBtu/ hr is the boiler design rating. Capacity = 86 MM Btu/ hr Heat input from test data Capacity defined as max heat input;

no change.

4 818 Soot blowing is used. Modified as requested 4 818 Stack Characteristics: Stack diameter = 8 ft,

Stack height = 250 ft. Data added 4 818 Haz. waste description = Flammable liquid (waste code D001) Haz. waste description = Resinate filer cake, HC920/ spage oil, acrylic process spent organics and overheads Modified as requested 4 818C10 Report Content = volatiles, semi vol, TOC. Report Content = Non D/ F organics (no PM, chlorine, metals, etc.) Modified as requested 4 818C10 BIF feed rate limit for Cl = 21,000 BIF feed rate limit for Cl = 29,000 Modified as requested 4 818C11 Report Details: Report name = Recertification Test Report, Testing Dates= June 29 30,1995,

Technical scope and measurements = D/ F,

Report preparer = Westvaco, Testing firm =

Emission Testing Services, Inc Report Details: Report name = 1998 Risk Burn Report, Testing Dates =

June/ July 1995, Technical scope and measurements = D/ F, PM, Report preparer = ?, Testing firm = ? Modified as requested 4 818C11 COC stack test conditions: Gas flowrate =74,852 dscfm, CO = 1.5 ppmv O2 = 13.1 % , Moisture = 5.24 % ,

Temperature = 357 o F Not available Data added 4 818C11 Provided actual gas sample volumes and oxygen levels for PCDD/ PCDF sampling train Estimated values based on best available information Updated using correct info as provided by commenter 4 818C12 Report Details: Technical scope and measurements = D/ F, PM ; Report preparer =

Walk, Haydel & Associates, Testing firm =

TRC Environmental Corp. Not available Data added 4 818C13 New Condition; Recertification of Compliance Test Report; Testing Dates = June 24 26,

1998; Contents = Feed, Stack gas parameters,

and D/ F data Report submitted with comment,

contained new condition, added new data 4 818C14 New Condition; Air Quality Compliance Test;

Testing Date = July 5, 1995; Contents = PM,

CO, THC, and Stack gas parameters. New Condition, added new data 5 764C1 765C1 766C1 Test conditions are under "normal" conditions Conditions identified as being conducted under maximum waste and ash feed levels No change made. CoC testing not done under "normal" conditions. 5 764C1 765C1 More recent updated BIF feed rate limits provided Old feedrate limits shown. Modified as requested 5 764 765 Stack Characteristics: Temperature = 529 o F,

Diameter = 5 ft, Velocity = 63. 7 ft/ s. Also note,

boilers have a common stack Data added 5 764 765 Should add "Adjusted" Tier I for all metals,

chlorine Tier I for all metals, chlorine Modified as requested 5 764C1R3 Sootblowing corrected PM emissions = 0.0398 gr/ dscf Uncorrected PM emissions level shown = 0.0662 gr/ dscf No change. Sootblowing corrected test condition average shown correctly.

5 764C1 Liquid waste thermal feedrate = 70.7 MM Btu/ hr Feedrate = 74 MM Btu/ hr Modified as requested 5 764C1 Ash feedrate = 6.126 lb/ hr Feedrate = 5.99 lb/ hr Modified as requested, although insignificant difference 5 764C1 Stack gas conditions should be: Gas flowrate= 18,657 dscfm; O2 = 8.1% Stack gas conditions estimated based on total thermal feedrate using standard F factor approach and typical estimated oxygen level. Gas flowrate = 17,037.2 dscfm; O2 = 7% Modified as requested 5 765C1R3 Sootblowing corrected PM emissions = 0.0411 gr/ dscf Uncorrected PM emissions shown =

0.0808 gr/ dscf No change. Sootblowing corrected test condition average shown correctly.

5 765C1 Liquid waste thermal feedrate = 72 MM Btu/ hr, Ash feedrate = 5.626 lb/ hr Liquid waste thermal feedrate = 72. 8 MM Btu/ hr, Ash Feedrate = 5. 6 lb/ hr Modified as requested, although insignificant differences 5 765C1 Stack gas conditions should be: gas flowrate= 17,518.7 dscfm; O2 = 5.5 % Stack gas conditions estimated based on total thermal feedrate and typical estimated oxygen level using standard F factor approach; Gas flowrate =

16,475.3 dscfm; O2 = 7% Modified as requested 5 766 EPA ID # NYD066832023 EPA ID # NYD06683023 Modified as requested 5 766 Soot blowing is used. Wasn't used during compliance testing, but is used under normal operations. Sootblowing status identified as "None" based on that used in compliance testing. Modified as requested. Note that sootblowing must be used during compliance testing if used during normal operations.

5 766 Natural gas is primary boiler fuel. Permitted to burn either #2 or 6 as auxiliary Natural gas identified as supplemental/ auxiliary fuel Added that fuel oil No. 2 and No. 6 may also be used as non waste fuels.

6 854 Source Descriptions should be modified:

Facility name = Eastman Chemical Company,

Texas Operations; Haz. waste description =

Liquid hazardous waste; Additional stack parameters provided: Stack height = 63 ft, Gas temp = 187F, Velocity = 44.1 ft/ s; Permitting Status = Adjusted BIF Tier I. Facility name = Texas Eastman Division; Haz. waste description =

By product liquid feed; Gas temp =

190F, Velocity = 45 ft/ s; Permitting Status = BIF Tier I for all metals Information added or modified as requested 6 854C1 Several Feedstream inputs should be modified slightly: Liq waste heat content = 1150 Btu/ lb;

vent gas heat content = 92. 3 Btu/ dscf; Chlorine in Liq waste = 813 lb/ hr; Chlorine in Vent gas = 29. 2 lb/ hr; POHC Chlorine spike = 4. 7 lb/ hr Liq waste heat content = 1200 Btu/ lb;

vent gas heat content = 100 Btu/ dscf;

Chlorine in Liq waste = 815 lb/ hr;

Chlorine in Vent gas = 28 lb/ hr; POHC Chlorine spike = 4. 6 lb/ hr Modified as requested, although insignificant differences 6 854C1 Dioxins and furan catches should correct for field blanks. Data base included uncorrected dioxins and furan catches. Convention is to report uncorrected dioxins and furan catches (not corrected for field blank).

6 854C2 Sampling Train 1  HCl/ Cl2, Run 1 and Run 2.

Switch stack gas flowrate, O2, moisture and temperature. Switched as requested 6 854C2 Several Feedstream inputs should be modified slightly: Liq waste Firing Rate = 9. 3 MMBtu/ hr; Liq waste Heating Value = 2144 Btu/ lb. Liq waste Firing Rate = 9.4 MMBtu/ hr ; Liq waste Heating Value = 2167 Btu/ lb. Modified as requested 7 778 Source Descriptions should be: Combustor Characteristics = John Zink LoNOx burner ;

Supplemental Fuel add, during start up and shutdown; Capacity (MMBtu/ hr) = 18.6;

Permitting Status = Adjusted Tier 1 for all BIF metals and chlorine/ chlorides; Recertification of Compliance Test = 8/ 27/ 98. Source Descriptions read: Combustor Characteristics = John Zinc LoNOx burner; Supplemental Fuel = Natural gas (start up only); Capacity (MMBtu/ hr) = 19 ; Permitting Status =

Tier I metals, chlorine (IA for Cr);

Recertification of Compliance Test Report = 9/ 27/ 98 Modified as requested 7 778C10 Calculations of the Cr +6 should equal: 7.81,

7.12, and 5.02 ug/ dscm @ 7% O2 for runs 2, 3,

and 3( soot correction) respectfully. Cr +6 values: 7.4, 6.8 ug/ dscm @ 7% O2 for runs 2, and 3 (soot correction). Cr +6 recalculated: 7.82, 7.12, and 5.08 ug/ dscm @ 7% O2 for runs 2, 3,

and 3( soot correction).

7 778C10 K083 liquid waste feed rates should be modified: Chlorine 50.7 (g/ hr) Mercury < 0.03 (g/ hr) Lead < 0.2 (g/ hr) Cadmium < 0.2 (g/ hr)

Arsenic < 0. 2 (g/ hr) Beryllium < 0. 2 (g/ hr). K083 liquid waste feed rates reported as: Chlorine 50. 9 (g/ hr) Mercury <

0.02 (g/ hr) Lead < 0.1 (g/ hr) Cadmium < 0.1 (g/ hr) Arsenic < 0.1 (g/ hr)

Beryllium < 0. 1 (g/ hr). Modified as requested, although insignificant differences 7 1000 Source Descriptions should be: Combustor Characteristics = John Zink LoNOx burner ;

Capacity (MMBtu/ hr) = 30. 3; Permitting Status = Adjusted Tier 1 for all BIF metals and chlorine/ chlorides; Content of Condition 1 included Cr+ 6 emissions tests. Source Descriptions read: Combustor Characteristics = John Zinc LoNOx burner; Capacity (MMBtu/ hr) = 30 ;

Permitting Status = Tier I metals,

chlorine (IA for Cr). Modified as requested 7 1000C1 CO MHRA should be modified to: Runs 3, 5,

and 6 are 3.8 ppmv, 9.9 ppmv, and 9.8 ppmv,

respectively CO MHRA reported as: 7.1, 3.9, 3.8 ppmv Modified as requested 7 1000C1 Stack gas flow rates should be modified to:

4100 dscfm, 4200 dscfm, and 4400 dscfm Stack gas flow rates reported as: 4000,

4300, 4100 dscfm Modified as requested, although differences are insignificant 7 1000C1 Ash and Chlorine liquid waste feed rates should be modified: 95.62 and 10.5 g/ hr Ash and Chlorine feed rates reported as: 95.7 g/ hr, 10.6 g/ hr Modified as requested, although differences are insignificant 7 1000C1 Stack gas conditions from Cr+ 6 sampling train omitted. Data added 8 853 New trial burn and supplemental trial burn Added new data (2 new test conditions, 853C11, 853C12) 8 853 APCS characteristics  3 stage HCl and vent scrubbers use water, Dynawave scrubber uses caustic Added as requested 8 853 Supplemental fuel  natural gas used only during startup, shutdown; not during normal operations Added as requested 8 853 Stack diameter at top is 1.5 ft 3 ft stack diameter Changed as requested 8 853 Permitting status  Tier I adjusted for all metals except Cr, Tier III for Cr and Cl Added as requested 8 853C10 Total waste feedrate = 4331 lb/ hr Feedrate estimated at 3886 lb/ hr based on measured stack gas flowrate. Not available in test report. Changed as requested 8 853C10 Firing rate = 48.2 MMBtu/ hr Estimated firing rate at 43.3 MMBtu/ hr based on measured stack gas flowrate. Changed as requested 8 853C10 Viscosity = < 6 cps Viscosity = 6 cps Added as requested 8 853C10 Process information included in attachments Information provided was not relevant for database 8 853C10 No spiking; all "other" and "spike" %'s should be zero Values left blank No change. A blank value indicates that no spiking took place. Also, a blank value in the "other" column indicates no contribution from the "other" streams.

9 780 Source Descriptions should be modified:

Permitting Status = under interim status; Soot blowing = one 10 min. soot blowing cycle (Condition 1 run 3). Permitting Status = Tier I metals and chlorine; Soot blowing = one soot blowing cycle (10 min.) (Cond 2 run 3). Modified as requested 9 780C1 Several flowrates/ feed rates should be modified: gas flowrate run 3, 27555 dscfm,

liquid solvent feedrate 1191.9 kg/ hr, ash feedrate 1236 g/ hr, chlorine feedrate 596 g/ hr. Flowrates/ feed rates read: gas flowrate 27550 dscfm, liquid solvent feedrate 1195.5 kg/ hr, ash feedrate 1300 g/ hr,

chlorine feedrate 595 g/ hr. Modified as requested, although differences are insignificant 9 780C2 Several feed rates should be modified: liquid solvent feedrate 231.6 kg/ hr, thermal feedrate 4.3 MMBtu/ hr. Feed rates read: Liquid solvent feedrate 234 kg/ hr, thermal feedrate 4.5 MMBtu/ hr. Modified as requested. Dependant cell, total thermal feedrate, also commented on.

9 781 Source Description should be modified:

Permitting Status = under interim status. Permitting Status = Tier I metals and chlorine. Modified as requested.

9 781C1 Several flowrates/ feed rates should be modified: run 1, gas flowrate 27383 dscfm,

liquid solvent feedrate 1181.3 kg/ hr, thermal feedrate 21.7 MMBtu/ hr, ash feedrate 1732 g/ hr, chlorine feedrate 591 g/ hr, lead feedrate 0.118 g/ hr. Flowrates/ feed rates read: Gas flowrate 273383 dscfm, liquid solvent feedrate 1185.5 kg/ hr, thermal feedrate 21 MMBtu/ hr, ash feedrate 1790 g/ hr,

chlorine feedrate 586 g/ hr, lead feedrate 0.13 g/ hr. Modified as requested, although differences are insignificant 10 721 Source Description should be modified:

combustor rating = 350,000 lb/ hr steam,

additional combustor characteristics provided;

Soot blowing discontinued; Additional haz.

waste description info; Stack characteristics:

height 50. 5 ft, velocity 28 ft/ sec; Permitting status adjusted Combustor rating = 35,000 lb/ hr steam;

Permitting status = Tier I for metals and chlorine. Information added or modified as requested 10 721C10 Should not the Mercury (Hg) Total reflect the fact that BOTH feeds had "nd" and mark "nd"

as well? Emissions and feedrate data summary sheet provides relative amount of the feedrate derived from non detects 10 721C10 Condition description should read "Risk burn;

typical feedrate." Risk burn; max feed rate Modified as requested 10 720 Stack Characteristics and several firing rates provided: Height = 133 ft; 5.1 MMBtu/ hr liquid waste methanol, 3. 3 MMBtu/ hr vent gas,

27. 0 MMBtu/ hr natural gas, Total firing rate of 35.4 MMBtu/ hour, Design firing rate of MH5A is ~68 MMBtu/ hr. Information added or modified as requested 13 855 Change facility name to Georgia Gulf Chemicals and Vinyls, LLC Georgia Gulf Changed as requested 13 855 Change Haz Waste Description to Liquid wastes  Heavy ends from the distillation of ethylene dichloride in ethylene dichloride production (K019) Liquid wastes  vinyl chloride monomer light ends (K022, K019) Changed as requested 13 855 The stack gas temperature is 104.39F Added 13 855 The stack gas velocity is 59 ft/ s Added 13 855 The unit's classification has been changed from incinerator to HAF Classified as a HAF, although noted that permitted as an incinerator;

expected to be renewed as a HAF Updated 13 855 Report preparer is Environmental Science &

Engineering, Inc. Added 13 855 Change the condition description number 12 to be the same as number 13 Trial burn  Heavy liquid waste feed Changed as requested 13 855 Request to calculate various condition averages Do not calculate condition averages here No change 13 855 Changes to POHC feedrate and DREs No changes. No signficant differences.

13 855 Change the feedrate for Cr (mg/ L) is 0. 9 The feedrate for Cr is 1 mg/ L No significant difference, although changed as requested 13 855C12, C13 Change the gas flowrate of C12 and C13 to the average of runs 1 6 Gas flowrate is average of runs 4 6 Separate the avg gas flow rate of C12 and C13 into two cond. The gas flowrate of C12 (run 1 3) is 11316.9 dscfm. The gas flowrate of cond. 13 (run 4 6) is 9951 dscfm 13 855C12, C13 Also change waste feedrate, O2, steam production, natural gas feed, boiler exit temp.,

liquor pH, water feed, liquor feed of C12 and C13 to average of runs 1 6 Levels shown as average of runs 4 6 Separate into two individual conditions as noted above.

13 2000 Change facility name to Georgia Gulf Chemicals and Vinyls, LLC Georgia Gulf Changed as requested 13 2000 Change the waste description to Liquid wastes  Distillation bottom tars from the production of phenol/ acetone from cumene (K022) Liquid wastes  Methanol and acetone/ phenols production byproducts (K022), distillation tars/ oil VCM. Changed as requested 13 2000 Change the stack characteristics: Diameter (6.7 ft), Height (100 ft), Gas velocity (50 ft/ sec),

and Gas temperature (460F) Diameter (4.75 ft), Height (42 ft), Gas Velocity (35. 6 ft/ sec) and Gas temperature (475.7 oF) Changed as requested 13 2000 Misspelled acetophenone acetephenone Changed as requested 13 2000 Request calculation of condition. averages No change. Unnecessary to calculate 13 2000C2 Change the gas flowrate of C2, sampling train 1 (PM). Run 1 is 26895.1 dscfm, run 2 is 29069.7 dscfm, run 3 is 26223.1 dscfm Flowrate of 26524 dscfm was estimated Changed as requested 13 2000 Remove the MTEC calculation for Cr+ 6 stack gas emissions. Move to feedrate section. Converted a mass emissions rate to a stack gas concentration. No change. A conversion from a mass rate (g/ hr) to a stack gas concentration is standard procedure.

13 2000C1 Change viscosity to 1073 cSt Viscosity is 1787.7 cSt Changed as requested 13 2000C1 Request various changes to feedrates No changes made. They do not make a significant difference.

13 2000 Request adding the estimated firing rate for Mixed Oil Not calculated No change. Only calculate the Estimated Firing Feedrate for total feedrates based on stack gas flowrate and O2, not per individual feedstream.

13 2000 Chlorine MTEC calculation references the wrong cell Changed as requested 13 2000 Requests minor changes for the values and units of Be, acetophenone and Viscosity Changed as requested 13 2000 Change OCDF in run 2 to 0.29 OCDF = 0.00029 Changed as requested 13 2000 Inconsistent procedure for reporting the Heat Input Rate (MM Btu/ hr) in summary sheet. For 2000C1 and 2000C2, based on waste feedrate and heating value.

For 2000C3, 2000C4, based on F

factor estimation. As clearly discussed in the database report, we use the one that is considered as most representative after calculation both on an estimated basis using an F factor approach for the total heat input, and based on reported feedrate input rates and heating values.

13 2000 Inconsistent procedure for handling data at the detection limit. Using half detection limit values for SVM, LVM calculations and in summary sheet. Everywhere else report full detection limits. See the database report for procedures for handling the non detects.

13 2000 Should use the average of multiple simultaneous sampling trains in summary sheet. Using values from only one sampling train. No change. Have chosen to represent the test condition by the sampling train that was run over the longest time duration, as discussed in the database report.

14 1002, 1003, 1004 Add new, more recent, CoC test conditions which were provided Added 2 new CoC test conditions for each facility 14 1002, 1003, 1004 Facility operator name has changed from Arco Chem to Lyondell Chemical Arco Chemical Made change 15 735 Capacity = 92 MM Btu/ hr Capacity = 91.8 MM Btu/ hr No change made; insignificant difference.

15 735 Sootblowing  Yes; 4 times/ day; 5 minutes/ event Sootblowing yes; 4 times/ day Added 15 735 Stack gas temp = 615F, velocity = 44.7 ft/ sec Added 15 Add risk modeling information such as dilution factor, land use, etc. Not added to database at this time.

Will condsider later when proceeding on risk assessment 15 Expand permitting status to include PM, DRE,

CO, waste feed limits, etc. Not necessary.

15 735C1, C2 and 737 C1 and C2 Remove old data (735 and 737 C1 and C2 for 1996 CoC) that is not most recent testing Older data included in database At this point, old data will be kept in the database. It will likely not be used for any MACT setting purposes.

15 735 Remove "s" from Boilers in Report Name/ Date Changed 15 735C3 Testing dates from Oct 21 23 Testing data from Oct 21 22 and Nov 22 Changed 15 735C3 Cr+ 6 testing done during earlier mini burn Cr+ 6 testing part of C3 Moved 15 735C6 Add new data from mini burn Added new test condition 15 735C7 Add new data from trial burn retest, which includes DRE for dichlorobenzene Added new test condition 15 735C3R3 Cl2 stack gas emissions is "nd" Added 15 735C3, C5, 737C3, C4 Supplied gas flowrates for PM/ Cl train that were missing Not available in copy of test report Added 15 735C3, C4, C5, 737C3, C4 Use Orsat O2 values, not CEMS as reported Only had CEMS O2 levels Replaced as suggested with supplied Orsat O2 values; although note that values are not significantly different 15 735C3 Stack gas temps should be 622, 634 and 632 Stack gas temps of 613, 616, 619 No significant difference 15 Should report max or min hourly rolling averages for process operating parameters Report average of each test run for process operating parameters, not max or min hourly rolling averages No change. Average of each run is most appropriate at this point.

15 735C3, C4 Max fuel feedrates should be used to calculate firing rates Average fuel feedrates used. No change. Although, note that difference between the average and max is not significant.

15 735C3 Corrections to various ash, and metals feedrates No changes. Differences not significant; for example, ash in fuel of 1687.01 vs 1686.7 g/ hr. 15 Objects to location of Tier I feedrate limits No change. Location is unimportant.

15 737 Add "Boiler" to unit ID Name Unit ID Name as "30K" Added 15 737 Sister Facilites  Boiler 70K for Cr+ 6 Sister Facilities  none No change. Boiler 70K has its own performance data (unit ID No. 735)

15 737C5 Add new trial burn retest data report Added new data under test condition 737C5 15 737C3 HC under R3 should be nd HC is listed as nd No change. Note that reporting a "nd" for a CEMS HC measurement is not appropriate or standard practice.

15 737C4R3 OCDD  8.61e 6; 2,3,7,8 TCDF  8.89e 5 nd OCDD exact same as requested, TCDF  need to add nd Added nd to TCDF. No significant impact on TEQ level 15 738 Sister Facilities  "Boiler 30K" Unit 737 (Boiler 30K) is used to represent Unit 738 (Boiler 28K).

28K is a sister of 30K. Thus data from 738 will not be used. At this time though it will remain in the database.

16 1018 Source Description should be modified:

Additional soot blowing information provided;

Several dispersion characteristics: Stack height = 45 ft, stack velocity = 25. 8 ft/ sec, gas temp =

576F; Permitting status = All metals except Cr Adjusted Tier I, Cr under Tier III Soot blowing not described in detail,

stack height and velocity not included in database. Temp measurements for two conditions: 1018C11 = 576,

1018C12= 725 Information added or modified as requested.

16 1018 BIF Feedrates provided Previously not available Data added 16 1018C10 Condition is better described as the maximum combustion temperature condition; Condition content = Feed analysis: 10 BIF metals (not chromium only), chlorides, and ash. PM, CO,

and Cr+ 6 and total Cr emissions. Trial burn; max combustion temp; PM,

CO, Cr+ 6, feed analysis for chromium and ash Modified as requested 16 1018C12 Condition is better described as the risk burn condition at maximum liquid waste feedrates and minimum natural gas flowrate Risk burn; max liquid waste fuel Modified as requested 16 1018C10 CO MHRA for Run 1 = 0.6ppmv 7% O2 0.06 ppmv 7% O2 Modified as requested. Dependant cells also commented on.

16 1018C10 Sampling train parameters for PM, hexavalent and total chromium train provided; Information not available Data added 16 1018C10 Additional feed stream data providedfor :

natural gas, ash modifier. Only liquid waste feed analysis shown Data added 16 1018C11 POHC total feedrates (feed and spike)

provided Data added 16 1018C11 1018C12 Additional feed stream data provided for natural gas Data added 16 1018C12 Metals feedrate condition averages should be modified: Ba < 10, Hg < 0.2, Tl < 24 Ba < 15.9, Hg < 0.267, Tl = 24 Modified calculations to be consistent in handling of non detect runs when calculating condition averages 17 812 More accurate description of Combustor Characteristics= Turbulent burner chamber,

closed coupled to a watertube waste heat boiler, 30 MMBtu/ hr installed 1985, 25,000 lb/ hr steam @ 215 psig. Combustor Characteristics = Waste heat boiler, 30 MMBtu/ hr, installed 1985, 25,000 lb/ hr steam @ 215 psig Modified as requested 17 812 Source Description should be modified: Stack Height = 100 ft, Permit status = Tier I adjusted except Cr+ 6 and HCl/ Cl2. Permit Status = Tier I adjusted except Cr+ 6 Information added or modified as requested 17 812C2 Several feed rates should be modified: Run 5,

LUWA Bottom total chlorine feedrate = 267 lb/ hr, Chromium feedrates = 5.36E 3, 5.48E 3,

5.15E 3lb/ hr Run 5, LUWA Bottom total chlorine feedrate 265 lb/ hr, Chromium feedrates = 5.0E 3, 5.0E 3, 5.0E 3lb/ hr Modified as requested 17 812C1 812C2 812C3 Units for Scrubber L/ G Ratio are lb/ lb Units for Scrubber L/ G Ratio =

gal/ kcaf? Modified as requested 17 813 More accurate description of Combustor Characteristics =Turbulent burner chamber closed coupled to a water tube waste heat boiler and economizer, Steam of 25,000 lb/ hr @ 350 psig. Combustor Characteristics = Steam of 25,000 lb/ hr @ 350 psig Modified as requested 17 813 Source Description should be modified: Stack velocity 78. 9 ft/ sec, Permit status= Tier I adjusted, Sootblowing = 6 min during 813C1 run 4. Stack velocity 78. 9ft/ min, No previous info on permit status or soot blowing. Information added or modified as requested 17 813C1 Average hydrogen feedrate should be modified = 106lb/ hr. Average hydrogen feedrate = 105 lb/ hr. Modified as requested 17 814 More accurate description of Combustor =

Process Heater/ Boiler; Primary function to superheat a raw material used in Diphenylamine production. Only a small portion of the total heat input is utilized for steam production. Combustor = Boiler. Modified as requested 17 814 Source Description should be modified: Stack Height = 75ft , Stack velocity 54. 1ft/ sec. No previous info on Stack Height,

Stack velocity 54. 1ft/ min. Information added or modified as requested.

17 814C2 Modify sampling train parameters( B run):

stack gas flowrate, moisture, and temperature. Modified as requested, although insignificant differences 17 814C2 Each (B run) Ash feedrate should be modified:

1.09,1.17,1.14 lb/ hr. Ash feedrates: 2.32,2.03,2.23 lb/ hr Modified as requested 17 815 More accurate description of Combustor =Process Heater/ Boiler; Primary function to superheat a raw material used in Diphenylamine production. Only a small portion of the total heat input is utilized for steam production. Combustor = Boiler. Modified as requested 17 815 More accurate description of Combustor Characteristics = Turbulent burner chamber,

separate tube banks Combustor Characteristics = Turbulent burner chamber. Modified as requested. 17 815 Source Description should be modified: Stack Height = 80.5ft , Stack velocity 34. 1ft/ sec. Stack Height = 41.5 ft, Stack velocity =

34.1 ft/ min. Modified as requested 17 815C1 Firing rate = 15.7 MMBTU/ hr. Firing rate = 17.0 MMBTU/ hr. Modified as requested 18 774 Source Description should be modified: Boiler Nos. 1, 2 and 4 sister facilities. Other Sister Facilities = none. Modified as requested 18 774 Additional stack parameters provided: Stack diameter = 6.5 ft, stack height = 63 ft, Gas temp = 441F, Velocity = 52.9 ft/ sec Data added 18 774C1 Sampling train parameters for PM provided;

Gas flowrate = 51467 dscfm, Moisture =

15.6%, Gas Temp = 441F Data added 18 774C1 Two feed rates should be modified: Ag feedrate in T 303 feed 0.17 g/ hr, Tl feedrate in T 303 feed 0.34 g/ hr. Ag feedrate in T 303 feed 2.06 g/ hr, Tl feedrate in T 303 feed 0.17 g/ hr. Modified as requested 18 774C1 774C2 Additional feed stream data provided: IPOH feedrate = 2182843 g/ hr, Natural gas heating value = 25089 Data added 19 729 Incorrect EPA ID No. (EPA CTD001159730) CTD001159731 Changed 19 851 Stack diameter = 8" at top; stack height = 74.5 ft above grade Changed 19 851C1 R1 and R2 HC = 0.5 ppmv HC = 0.6 ppmv Corrected 19 851C1 Miscalculations of arsenic, chromium, nickel,

and chlorine stack gas emissions concentrations Corrected 19 851 Incorrect POHC emissions rates Corrected 19 851C1 Incorrect Cr stack gas emission rates Corrected 19 851 Incorrect PCDD/ PCDF sampling train parameters Corrected 19 851 Incorrect Ba feedrate Corrected 19 851 Incorrect 2,3,6,7,8 HpCDD entry Corrected (61.6 vs 61.1)

19 786, 788, 843, 845, 2017, 2018 Couple of incorrect feedrates No change. Feedrates doublechecked and are OK.

19 Many Dow facilities Missing Tier I and III feedrate limits Not provided. Will add when available.

19 2017C1 R1 PM = 0.0062 R1 PM = 0.0054 No change. PM of 0.0054 is correct at 7% O2. Although, R2 and R3 were incorrectly given at stack gas conditions. These are correct with levels at 7% O2.

22 907 Boiler No. 15 (ID No. 907) is no longer in service. Has been closed. Unit identified as no longer burning hazardous waste 22 910 Sister unit Boiler No. 4 is no longer burning hazardous waste Changed as requested 22 908 Burns both pulverized coal and natural gas as supplemental fuels Coal as supplemental fuel Added 22 753 Very small changes to BIF Tier I feedrate limits No change; insignificant difference 23 740 Source Descriptions should be modified:

Facility Name = Rohm and Haas Texas,

Incorporated; Combustor = Furnace with watertube boiler; Stack Characteristics:

Diameter (ft) = 9, Height (ft) = 144 Rohm and Haas; Watertube boiler;

Diameter (ft) = 9.2, Height (ft) = 150 Modified as requested 23 740 Feedrate MTEC Calculations Chlorine (nd) = 3613 Lead (nd) = 12.3 Cadmium (nd) = 6.2 Chromium (nd) = 6.2 Feedrate MTEC Calculations Chlorine (nd) = 3605 Lead (nd) = 11.7 Cadmium (nd) = 5.8 Chromium (nd) = 5.8 Commenter used less signifigant figure and calculated MTEC incorrectly; no changes made.

23 740 SVM [Cd & Pb] = 17.5 LVM [As, Be & Cr (Total)] = 124 SVM [Cd & Pb] = 8.8 LVM [As, Be & Cr (Total)] = 62 No change. SVM and LVM calculation non detect value( s) is divided by 2 (use of "one half" of the detection limit).

23 740 Total Estimated Firing Rate = 101.5 MM Btu/ hr Estimated based on total thermal feedrate using standard F factor approach. 212.5 MM Btu/ hr Modified as requested.

23 741 Source Descriptions should be modified:

Facility Location = Louisville, KY; Should add "Adjusted" Tier I for all metals, chlorine Knoxville, TN; Tier I for all metals,

chlorine Modified as requested.

23 741 Stack Characteristics: Diameter (ft) = 6.5;

Requested footnote for gas velocity and temperature. "At sample location on stack which has a diameter of 7.83 feet." Data added.

23 741 Report Details: Report preparer = Focus Environmental, Inc.; Testing firm = TRC Environmental Corporation; Content = PM,

CO in stack gas; metals, chlorine and ash in feedstreams Report Details: Report preparer = TRC Environmental Corporation; Testing firm = Focus Environmental, Inc.;

Content = PM, CO in stack gas; metals,

chlorine in feedstreams Modified as requested 23 741 PM emission rate (g/ hr): Run 1 = 5,339; Run 2 = 5,796; Run 3 = 8,387; Corrected Soot Blowing Avg = 5,857 PM emission rate (g/ hr): Run 1 =

5,430; Run 2 = 5,820; Run 3 = 8,294;

Corrected Soot Blowing Avg = not reported Modified as requested, although insignificant differences. Soot corrected average verified and updated. 23 741 Minor Changes Recommended:

Main gun feedrate (lb/ hr) = 9, 302 Side gun feedrate (lb/ hr) = 3, 091 Natural gas heating value (Btu/ scf) =

1,022 Gas feedrate (dscfh) = 50,400 Antimony feedrate (g/ hr) = 17. 1 Arsenic feedrate (g/ hr) = 14.1 Lead feedrate (g/ hr) = 56.2 Thallium feedrate (g/ hr) = 112 Combustion Temperature ( o F) = 2,117 Steam Production Rate (lb/ hr)= 154,300 Main gun feedrate (lb/ hr) = 9, 300 Side gun feedrate (lb/ hr) = 3, 100 Natural gas heating value (Btu/ scf) =

1,000 Gas feedrate (dscfh) = 50,000 Antimony feedrate (g/ hr) = 17 Arsenic feedrate (g/ hr) = 14 Lead feedrate (g/ hr) = 56 Thallium feedrate (g/ hr) = 110 Combustion Temperature ( o F) = 2,100 Steam Production Rate (lb/ hr)= 152,000 Modified as requested 23 741 New feed information:

Main gun heating value( Btu/ hr)= 11, 000 Side gun heat value( lb/ hr) = 17, 000 Spiking feedrate (lb/ hr) = 31 Spiking heating value (Btu/ lb) = 8, 393 Spiking estimated firing rate (MM Btu/ hr) = 0.3 Data added.

23 741 Chlorine feedrate (g/ hr) = 1,691 Barium feedrate (g/ hr) = 1.1 Hazardous waste estimated firing rate (MM Btu/ hr) = 154.9 Chlorine feedrate (g/ hr) = 1,900 Barium feedrate (g/ hr) = 11 Hazardous waste estimated firing rate (MM Btu/ hr) = 165.5 Modified as requested.

23 741 Feedrate MTEC Calculations Mercury MTEC (ug/ dscm) (nd) = 4 Beryllium MTEC (ug/ dscm) (nd) = 7 etc. Mercury MTEC (ug/ dscm) (nd) = 3 Beryllium MTEC (ug/ dscm) (nd) = 8 Modified feedrates. Note that commenter calculation excluded oxygen correction.

23 741 Feedrate MTEC Calculations SVM [Cd & Pb] (ug/ dscm) = 800 LVM [As, Be & Cr (Total)] (ug/ dscm) = 755 Feedrate MTEC Calculations SVM [Cd & Pb] (ug/ dscm) = 347 LVM [As, Be & Cr (Total)] (ug/ dscm)

= 340 No change. SVM and LVM calculation non detect value( s) is divided by 2 (use of "one half" of the detection limit). Appendix III. Data Summary Sheet Acronym List B Baseline Comm Commercial incinerator HW Hazardous waste IB In between MB Mini burn N No spiking N Normal NA Not appropriate NE Not evaluated OS Onsite incinerator PT Performance Test RB Risk Burn RT Research testing SRE System removal efficiency TB Trial Burn U Unknown WC Worst case Y Yes spiking Air Pollution Control Device Acronyms AA Acid absorber AB Afterburner ABS Absorber (packed bed scrubber) BH Baghouse C Cyclone CA Carbon adsorber CB Carbon bed CCS Counter current scrubber CFS Cross flow scrubber CHEAF Mist eliminator filter CI Carbon injection CS Caustic scrubber CSC Caustic scrubber DA Dilution air DI Dry injection scrubbing DM Demister DS Dry scrubber ES Entrainment separator ESP Electrostatic precipitator FF Fabric filter GC Gas cooler GS Gas subcooler HE Heat exchanger HES High energy scrubber HEPA High efficiency particulate air filter HTHE High temperature heat exchanger HS Hydrosonic scrubber IDF Induced draft fan IWS Ionizing wet scrubber LTHE Low temperature heat exchanger MC Multiple cyclones ME Mist eliminator OS Orifice scrubber PB Packed bed scrubber PBS Packed bed scrubber PCS Packed column scrubber PT Packed tower scrubber PTWS Packed tower wet scrubber Q Quench QC Quench column QS Quench separator QS Quench system QT Quench tower RJS Reverse jet scrubber S Scrubber (wet) SC Scrubber (wet) SC Spray column SD( A) Spray dryer adsorber SP Separator SS Spray saturator ST Spray tower VS Venturi scrubber WCS Packed bed water scrubber WESP Wet electrostatic precipitator WHB Waste heat boiler WS Wet scrubber


[Federal Register: August 10, 2007 (Volume 72, Number 154)]
[Notices]
[Page 45030]
[DOCID:fr10au07-64]

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DEPARTMENT OF ENERGY

Federal Energy Regulatory Commission

[Docket No. CP04-14-008]

Saltville Gas Storage Company, LLC.; Notice of Compliance Filing

August 6, 2007.
    Take notice that on July 31, 2007, Saltville Gas Storage Company,
LLC. (Saltville) tendered for filing as part of its FERC Gas Tariff,
Volume No. 1, tariff sheets in Appendix A to become effective September
1, 2007.
    Saltville states that this filing is being made in compliance with
the Commission's orders in Saltville Gas Storage Company, LLC., 107
FERC ] 61,267, order on reh'g, 109 FERC ] 61,200 (2004), order on
compliance, 110 FERC ] 61,318 (2005).
    Saltville further states that copies of its filing have been served
on all affected customers and interested state commissions.
    Any person desiring to protest this filing must file in accordance
with Rule 211 of the Commission's Rules of Practice and Procedure (18
CFR 385.211). Protests to this filing will be considered by the
Commission in determining the appropriate action to be taken, but will
not serve to make protestants parties to the proceeding. Such protests
must be filed on or before the date as indicated below. Anyone filing a
protest must serve a copy of that document on all the parties to the
proceeding.
    The Commission encourages electronic submission of protests in lieu
of paper using the ``eFiling'' link at http://www.ferc.gov. Persons

unable to file electronically should submit an original and 14 copies
of the protest to the Federal Energy Regulatory Commission, 888 First
Street, NE., Washington, DC 20426.
    This filing is accessible on-line at http://www.ferc.gov, using the

``eLibrary'' link and is available for review in the Commission's
Public Reference Room in Washington, DC. There is an ``eSubscription''
link on the Web site that enables subscribers to receive e-mail
notification when a document is added to a subscribed docket(s). For
assistance with any FERC Online service, please e-mail
<EMAIL_ADDRESS>or call<PHONE_NUMBER> (toll free). For

TTY, call<PHONE_NUMBER>.
    Comment Date: 5 p.m. Eastern Time on August 13, 2007.

Kimberly D. Bose,
Secretary.
 [FR Doc. E7-15659 Filed 8-9-07; 8:45 am]

BILLING CODE 6717-01-P