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-IR- Database: Indiana Register
IAC Titles     Current IR
TITLE 326 AIR POLLUTION CONTROL DIVISION

Final Rule
LSA Document #11-356(F)

DIGEST

Amends 326 IAC 7-2-1, 326 IAC 7-4-2, 326 IAC 7-4-3, and 326 IAC 7-4-11 concerning sulfur dioxide (SO2) emission limitations. Adds 326 IAC 7-1.1-3, 326 IAC 7-4-2.1, 326 IAC 7-4-3.1, 326 IAC 7-4-11.1, and 326 IAC 7-4-15 concerning the new 1-hour SO2 National Ambient Air Quality Standard (NAAQS). Repeals 326 IAC 7-4-2, 326 IAC 7-4-3, and 326 IAC 7-4-11. Partially effective 30 days after filing with the Publisher and partially effective January 1, 2017.


HISTORY
First Notice of Comment Period: June 29, 2011, Indiana Register (DIN: 20110629-IR-326110356FNA).
Continuation of First Notice of Comment Period: September 25, 2013, Indiana Register (DIN: 20130925-IR-326110356FCA).
Second Notice of Comment Period: September 10, 2014, Indiana Register (DIN: 20140910-IR-326110356SNA).
Notice of First Hearing: September 10, 2014, Indiana Register (DIN: 20140910-IR-326110356PHA).
Change in Notice of Public Hearing: December 24, 2014, Indiana Register (DIN: 20141224-IR-326110356CHA).
Date of First Hearing: March 11, 2015.
Proposed Rule: April 22, 2015, Indiana Register (DIN: 20150422-IR-326110356PRA).
Notice of Second Hearing: April 22, 2015, Indiana Register (DIN: 20150422-IR-326110356PHA).
Date of Second Hearing: July 8, 2015.


SECTION 1. 326 IAC 7-1.1-3 IS ADDED TO READ AS FOLLOWS:

326 IAC 7-1.1-3 Compliance date

Authority: IC 13-14-8; IC 13-17
Affected: IC 13-15; IC 13-17

Sec. 3. The emission limitations in 326 IAC 7-4-2.1, 326 IAC 7-4-3.1, 326 IAC 7-4-11.1, and 326 IAC 7-4-15 are effective January 1, 2017.
(Air Pollution Control Division; 326 IAC 7-1.1-3; filed Sep 2, 2015, 1:50 p.m.: 20150930-IR-326110356FRA)


SECTION 2. 326 IAC 7-2-1 IS AMENDED TO READ AS FOLLOWS:

326 IAC 7-2-1 Reporting requirements; methods to determine compliance

Authority: IC 13-14-8; IC 13-17-3-4; IC 13-17-3-11

Sec. 1. (a) As used in this article, "weighting factor" means the daily quantity of coal bunkered or megawatt generation or other appropriate measure of the output of a combustion source.

(b) As used in this article, "rolling weighted average sulfur dioxide emission rate" means the summation of the average sulfur dioxide emission rate times the daily weighting factor divided by the summation of the weighting factors.

(c) Owners or operators of sources or emissions units subject to 326 IAC 7-1.1, 326 IAC 7-4, or 326 IAC 7-4.1 shall submit to the commissioner the following reports based on fuel sampling and analysis data obtained in accordance with procedures specified under 326 IAC 3-7:
(1) Fuel combustion sources with total coal-fired heat input capacity greater than or equal to one thousand five hundred (1,500) million British thermal units (MMBtu) per hour shall submit quarterly reports of the thirty (30) day rolling weighted average sulfur dioxide emission rate in pounds per MMBtu. Records of the daily average coal sulfur content, coal heat content, weighting factor, and daily average sulfur dioxide emission rate in pounds per MMBtu shall be submitted to the department in the quarterly report and maintained by the source owner or operator for a period of at least two (2) years.
(2) Fuel combustion sources with total coal-fired heat input capacity greater than one hundred (100) and less than one thousand five hundred (1,500) MMBtu per hour shall submit quarterly reports of the calendar month average coal sulfur content, coal heat content, and sulfur dioxide emission rate in pounds per MMBtu and the total monthly coal consumption.
(3) All other fuel combustion sources shall submit reports of calendar month average sulfur content, heat content, fuel consumption, and sulfur dioxide emission rate in pounds per MMBtu upon request.

(d) Fuel sampling and analysis data shall be collected pursuant to the procedures specified in 326 IAC 3-7-2 or 326 IAC 3-7-3 for coal combustion or 326 IAC 3-7-4 for oil combustion. Computation of calculated sulfur dioxide emission rates from fuel sampling and analysis data shall be based on the emission factors contained in U.S. EPA publication AP-42* unless other emission factors based on site-specific sulfur dioxide measurements are approved by the commissioner and U.S. EPA. Fuel sampling and analysis data shall be collected as follows:
(1) For coal-fired fuel combustion sources with heat input capacity greater than or equal to one thousand five hundred (1,500) MMBtu per hour, compliance shall be determined using a thirty (30) day rolling weighted average sulfur dioxide emission rate in pounds per MMBtu unless a shorter averaging time or alternate averaging methodology is specified for a source under this article.
(2) For all other combustion sources, compliance shall be determined using a calendar month average sulfur dioxide emission rate in pounds per MMBtu unless a shorter averaging time or alternate averaging methodology is specified for a source under this article.

(e) Subsection (c) does not apply when continuous emission monitoring data collected and reported under 326 IAC 3-5 is used as the means for determining compliance with the emission limitations in this article.

(f) Owners or operators of sources or emission units subject to a restriction on the number of operating hours in 326 IAC 7-4 shall maintain, and make available to the department upon request, a log of operating hours for each emission unit.

(g) When determining compliance using continuous emission monitoring data, the diluent cap methodology under 40 CFR 75 may be used to calculate emissions in lbs/MMBtu.

(f) (h) Compliance or noncompliance with the emission limitations contained in 326 IAC 7-1.1 or 326 IAC 7-4 may be determined by an appropriate method as follows:
(1) A stack test conducted in accordance with 326 IAC 3-6 using procedures in 40 CFR 60, Appendix A, Method 6*, 6A*, 6C*, or 8*.
(2) A continuous emission monitoring system in accordance with 326 IAC 3-5.
(3) Source sampling in accordance with 326 IAC 3-6.
(4) Fuel sampling and analysis data collected in accordance with subsection (d) or 326 IAC 3-7.
(5) Other methods approved by the commissioner and U.S. EPA.

*These documents are incorporated by reference. Copies may be obtained from the Government Printing Office, 732 North Capitol Street NW, Washington, D.C. 20401 or are available for review and copying at the Indiana Department of Environmental Management, Office of Air Quality, Legal Counsel, Indiana Government Center North, Tenth Floor, Thirteenth Floor, 100 North Senate Avenue, Indianapolis, Indiana 46204.
(Air Pollution Control Division; 326 IAC 7-2-1; filed Aug 28, 1990, 4:50 p.m.: 14 IR 52; filed Jan 30, 1998, 4:00 p.m.: 21 IR 2078; errata filed Feb 9, 1999, 4:06 p.m.: 22 IR 2006; readopted filed Jan 10, 2001, 3:20 p.m.: 24 IR 1477; errata filed Nov 7, 2001, 3:00 p.m.: 25 IR 813; errata filed Dec 12, 2002, 3:30 p.m.: 26 IR 1565; filed Aug 26, 2004, 11:30 a.m.: 28 IR 42; filed May 25, 2005, 10:50 a.m.: 28 IR 2953; filed Aug 11, 2011, 1:54 p.m.: 20110907-IR-326050330FRA; filed Sep 2, 2015, 1:50 p.m.: 20150930-IR-326110356FRA)


SECTION 3. 326 IAC 7-4-2 IS AMENDED TO READ AS FOLLOWS:

326 IAC 7-4-2 Marion County sulfur dioxide emission limitations before January 1, 2017

Authority: IC 13-14-8; IC 13-17-3-4

Sec. 2. The following Before January 1, 2017, sources and facilities emission units located in Marion County shall comply with the sulfur dioxide emission limitations in pounds per million Btu (lbs/MMBtu) and pounds per hour (lbs/hr), unless otherwise specified, and other requirements, as follows:
  Source  Facility Emission Unit Description  Emission Limitations lbs/MMBtu  Emission Limitations lbs/hr 
  (1) Acustar  Boiler 1  2.82  109.98 
    Boiler 2  2.82  109.98 
    Boiler 3  2.82  109.98 
  (2) Allison Gas Turbine-  Boiler 1  3.99  299.4 
  Plant 5  Boiler 2  3.99  299.4 
    Boiler 3  3.99  299.4 
    Boiler 4  3.99  299.4 
  (3) Amtrak  Boilers 61 and 62  3.30  208.15 
  (4) Bridgeport Brass  Boiler 1  3.55  135.8 
    Boiler 2  3.55  135.8 
    Boiler 3  3.55  135.8 
  (5) Central Soya  Boiler  4.32  272.0 
  (6) Central State  Boiler 3  3.39  111.8 
    Boiler 7  3.39  169.5 
    Boiler 8  3.39  169.5 
  (7) Detroit Diesel Allison-  Boiler 1  1.88  67.6 
  Plant 3  Boiler 2  1.88  67.6 
    Boiler 3  1.88  90.2 
    Boiler 4  1.88  135.2 
    Boiler 5  1.88  180.3 
  (8) Diamond Bathurst  #2 Furnace  1.40 pounds per ton  20.22 
  (9) Ford  Boiler 1  2.43  177.38 
    Boiler 2  2.43  354.77 
    Boiler 3  2.43  354.77 
  (10) Fort Harrison  Boiler 1  2.92  151.84 
    Boiler 2  2.92  151.84 
    Boiler 3  2.92  151.84 
    Boiler 4  2.92  151.84 
  (11) G.M. Truck & Bus  Boiler 1  2.31  187.1 
  Group  Boiler 2  2.31  187.1 
    Boiler 3  2.31  106.3 
  (12) Indiana Girls School  Boiler  6.00  46.9 
  (13) IPL-Perry W  Boiler 17  6.0  1,320.0 
    Boiler 18  6.0  1,320.0 
  (14) Indianapolis Sludge Incinerator (1) Belmont Advanced Wastewater  (A) Incinerator 1  2.0 pounds per ton  14.19 
  Treatment Plant  (B) Incinerator 2  2.0 pounds per ton  14.19 
  Source ID No. 00032  (C) Incinerator 3  2.0 pounds per ton  14.19 
    (D) Incinerator 4  2.0 pounds per ton  14.19 
    Incinerator 5  2.0 pounds per ton  14.19 
    Incinerator 6  2.0 pounds per ton  14.19 
    Incinerator 7  2.0 pounds per ton  14.19 
    Incinerator 8  2.0 pounds per ton  14.19 
  (15) Marathon Petroleum-  H-H1  1.92  36.46 
  Indiana Refining Division  H-H2  1.92  36.46 
    H-H3  1.92  38.38 
    P-H1  1.92  89.03 
    P-H2  1.92  82.12 
    P-H3  1.92  30.32 
    P-H4  1.92  33.19 
    P-H5  1.92  9.98 
    Alky Reboiler  1.92  53.15 
    Crude Heater  1.92  268.05 
    Vacuum Heater  1.92  99.20 
    Sulfur Recovery  189.0 pounds per ton sulfur  88.17 
    FCC (Proc)  3.92 pounds per ton  506.37 
    CO Boiler  1.92  228.72 
    FCC Chg. Htr.  1.92  88.26 
    GH-1  1.92  81.36 
  (16) Navistar  Boiler 1  2.98  193.72 
    Boiler 2  2.98  193.72 
    Boiler 3  2.98  193.72 
  (17) Quaker Oats  Boiler 1  2.79  195.3 
    Boiler 2  2.79  195.3 
    Murray Boiler  0.50  50.1 
  (18) (2) Quemetco Source ID No. 00079  Reverberatory Furnace  24.6 pounds per ton  617.0 
  (19) Refined Metals  Blast Furnace  10.8 pounds per ton  64.8 
  (20) Reilly Industries (3) Vertellus  (A) 2722 W  1.25  114.75 
  Agriculture and Nutrition  (B) 2726 S  1.25  49.1 
  Specialties  (C) 186 N  1.25  46.0 
  Source ID No. 00315  (D) 2707 V  1.25  20.0 
    (E) 112 E  0.0**  0.0** 
    2710 P  0.0**  0.0** 
    Riley  1.25  64.75 
    B & W  1.25  49.1 
    (F) 2724 W  1.25  26.3 
    (G) 2714 V  1.25  18.8 
    (H) 2729 Q  1.25  3.8 
    (I) 2740 Q  1.25  7.5 
    (J) 732714  1.25  45.0 
    (K) 2728 S  1.25  7.5 
    (L) Still  0.0** less than 0.05  0.0** 
    (M) Kettle  0.0** less than 0.05  0.0** 
    (N) 2607 T  0.0** less than 0.05  0.0** 
    702611  0.0**  0.0** 
    (O) 722804  0.0** less than 0.05  0.0** 
    (P) 2706 Q  0.0** less than 0.05  0.0** 
    2713 W  0.0**  0.0** 
    2714 W  0.0**  0.0** 
    2720 W  0.0**  0.0** 
  (21) Rexnord-Link Belt  Boiler A  3.28  101.7 
  Bearing  Boiler B  3.28  101.7 
    Boiler C  0.0*  0.0* 
  (22) Rexnord-Link Belt  Boiler 1  3.68  117.8 
  Chain  Boiler 2  3.68  117.8 
    Boiler 3  3.68  117.8 
  (23) Thomson Consumer  Boiler 1  1.95  39.0 
  Electronics  Boiler 2  1.95  39.0 
    Boiler 3  1.95  146.3 
    Boiler 4  1.95  146.3 
  (24) Union Carbide  Boiler 1  3.85  92.4 
    Boiler 2  3.85  106.6 
    Boiler 3  3.85  148.2 
  (25) Western Select  Boiler 2  2.52  189.06 
  Properties  Boiler 3  2.52  189.06 
    Boiler 4  2.52  189.06 
    Boiler 5  2.52  252.07 
  (26) Wishard  Boiler 1  4.04  105.0 
    Boiler 2  4.04  105.0 
    Boiler 3  4.04  105.0 
  **Less than 0.05       
(27) Allison Gas Turbine Operations (4) Rolls-Royce Corporation Plant 8, Source ID No. 00311, shall comply with the sulfur dioxide emission limitations provided in clause (A) or (B) and other requirements as follows:
(A) Babcock and Wilcox Boilers 2 through 11 3 (0070-58), 4 (0070-59), and Combustion Engineering Boilers 7 through 10 (0070-62 through 0070-65) may burn either:
(i) natural gas at any time; or
(B) Babcock and Wilcox Boilers 2 through 6 and Combustion Engineering Boilers 7 through 11 may burn (ii) fuel oil with a sulfur dioxide emission limitation of two and one-tenth (2.1) lbs/MMBtu each during periods when one (1) of the following conditions is met either
(i) Fuel oil is burned in no more than three (3) Babcock and Wilcox boilers, and fuel oil is not burned in any combustion engineering boiler.
(ii) fuel oil is burned in no more than:
(AA) two (2) Babcock and Wilcox boilers and no more than two (2) combustion engineering boilers; or
(iii) Fuel oil is burned in no more than (BB) one (1) Babcock and Wilcox boiler and no more than three (3) combustion engineering boilers.
(C) (B) A log of hourly operational status and fuel type for each boiler shall be maintained at the plant and made available to the department upon request.
(C) A daily summary of operating status and fuel type for each boiler for each day of a calendar quarter shall be submitted to the department on a quarterly basis.
(D) Allison Gas Turbine Operations Rolls-Royce Corporation Plant 8 shall erect maintain a twenty (20) foot stack extension with a diameter at the extension outlet of four (4) feet for each stack serving Boilers 2 through 6 in accordance with the following schedule:
(i) Complete design, specifications, and construction drawings and award contracts by August 2, 1988.
(ii) Complete installation of stack extensions by December 2, 1988. 3 (0070-58) and 4 (0070-59).
(28) Indianapolis Power and Light (5) Citizens Thermal, C.C. Perry K Steam Plant, Source ID No. 00034, shall comply with the sulfur dioxide emission limitations in lbs/MMBtu and other requirements as follows:
  Boiler Number  Emission Limitations 
  (A) 17 and 18  0.3 
  (B) 11, 12, 13, 14, 15, and 16  2.1 
(A) Boiler numbers 17 and 18 shall not exceed three-tenths (0.3) lbs/MMBtu.
(B) Boiler numbers 11, 12, 13, 14, 15, and 16 shall not exceed two and one-tenth (2.1) lbs/MMBtu.
(C) As an alternative to the emission limitations in clause (B), sulfur dioxide emissions from Boilers 11, 12, 13, 14, 15, and 16 may comply with any one (1) of the sets of emission limitations in lbs/MMBtu as follows:
    Boiler Number  Emission Limitations 
  (i)  13, 14, 15, and 16  0.0 
    11 and 12  4.4 
  (ii)  11, 12, 15, and 16  0.0 
    13 and 14  4.4 
  (iii)  11, 12, 13, and 14  0.0 
    15 and 16  4.4 
  (iv)  11, 12, 15, and 16  3.0 
    13 and 14  0.3 
  (v)  11 and 12  0.3 
    13, 14, 15, and 16  3.0  
(D) Citizens Thermal shall notify the department or the Indianapolis Air Pollution Control Division shall be notified prior to the reliance use by Indianapolis Power and Light on Citizens Thermal of any one (1) of the sets of alternative emission limitations specified in clause (C).
(E) A log of hourly operating status for each boiler shall be maintained and made available to the department upon request.
(F) A daily summary indicating which boilers were in service during the day shall be submitted to the department quarterly. In addition, records of the daily average sulfur content, heat content, and sulfur dioxide emission rate for each day in which an alternative set of emission limitations specified in clause (C) is used shall be submitted to the department quarterly.
(F) (G) For the purposes of 326 IAC 7-2-1(c)(1), 326 IAC 7-2-1(d)(1), during thirty (30) day periods in which Indianapolis Power and Light Citizens Thermal relies on more than one (1) set of emission limitations specified in clauses (B) through and (C), a separate thirty (30) day rolling weighted average for each set of limitations shall be determined. Each thirty (30) day rolling weighted average shall be based on data from the previous thirty (30) operational days within the last ninety (90) days for that set of limitations. If Indianapolis Power and Light Citizens Thermal does not operate thirty (30) days under any one (1) set of limitations within the last ninety (90) days, the rolling weighted average shall be based on all operational days within the last ninety (90) days for that set of limitations.
(G) Boilers 11 through 16 shall be limited to six and zero-tenths (6.0) lbs/MMBtu each until Boilers 11 through 16 achieve compliance with the sulfur dioxide emission limitations specified in clauses (B) through (C). Compliance with the emission limitations specified in clauses (B) through (C) shall be achieved according to the following schedule:
(i) Complete engineering analysis of modifications by April 2, 1988.
(ii) Complete testing and design of modifications and place orders for necessary equipment by May 2, 1989.
(iii) Complete installation of necessary equipment and achieve compliance with emission limitations specified in clauses (B) through (C) by June 2, 1990.
(29) (6) Indianapolis Power and & Light Stout Company Harding Street Generating Station, Source ID No. 00033, shall comply with the sulfur dioxide emission limitations in lbs/MMBtu and other requirements as follows:
    Boiler/Turbine Number  Emission Limitations 
  (A)  Boiler 70  5.3 
  (B)  Boilers 50 and 60  4.7 
    Boilers 1 through 8  0.0 
    Boilers 9 and 10 and Gas Turbines 1, 2, and 3  0.35 
(C) As an alternative to the emission limitations in clause (B), sulfur dioxide emissions from Boilers 50, 60, and 1 through 10 and Gas Turbines 1, 2, and 3 may comply with any one (1) of the sets of emission limitations in lbs/MMBtu as follows:
    Boiler/Turbine Number  Emission Limitations 
  (i)  Boilers 50 and 60  5.2 
    Boilers 1 through 10 and Gas Turbines 1, 2, and 3  0.0 
  (ii)  Boilers 50 and 60  5.0 
    Boilers 1 through 10  0.0 
    Gas Turbines 1, 2, and 3  0.4 
  (iii)  Boilers 50 and 60  4.1 
    Boilers 1 through 8  0.26 
    Boilers 9 and 10  0.35 
    Gas Turbines 1, 2, and 3  0.3 
  (iv)  Boilers 50 and 60  3.9 
    Boilers 1 through 8  0.34 
    Boilers 9 and 10 and Gas Turbines 1, 2, and 3  0.35 
(D) Indianapolis Power & Light Company shall notify the department or the Indianapolis Air Pollution Control Division shall be notified prior to the reliance use by Indianapolis Power and & Light on Company of any one (1) of the sets of alternative emission limitations specified in clause (C).
(E) A log of hourly operating status for each boiler shall be maintained and made available to the department upon request.
(F) A daily summary indicating which boilers were in service during the day shall be submitted to the department quarterly. In addition, records of the daily average sulfur content, heat content, and sulfur dioxide emission rate for each day in which an alternative set of emission limitations specified in clause (C) is used shall be submitted to the department quarterly.
(F) (G) For the purposes of 326 IAC 7-2-1(c)(1), 326 IAC 7-2-1(d)(1), during thirty (30) day periods in which Indianapolis Power and & Light Company relies on more than one (1) set of emission limitations specified in clauses (B) through and (C), a separate thirty (30) day rolling weighted average for each set of limitations shall be determined. Each thirty (30) day rolling weighted average shall be based on data from the previous thirty (30) operational days within the last ninety (90) days for that set of limitations. If Indianapolis Power and & Light Company does not operate thirty (30) days under any one (1) set of limitations within the last ninety (90) days, the rolling weighted average shall be based on all operational days within the last ninety (90) days for that set of limitations.
(G) (H) Indianapolis Power and & Light Company shall install and maintain a stack diameter restriction for the stack serving Boilers 50 and 60. The stack diameter restriction shall reduce the diameter to six and one-half (6 1/2) feet at the tip of the stack. The installation of the stack diameter restriction shall be in accordance with the following schedule:
(i) Complete preliminary design of modifications by December 2, 1988.
(ii) Place orders for necessary modification by July 2, 1989.
(iii) Complete installation by February 2, 1990.
(30) Citizens Gas & Coke Utility shall comply with the sulfur dioxide emission limitations, depending on which battery or combination of batteries are in operation, as follows:
  Description  Emission Limitations (lbs/ton of coal)  Emission Limitations (lbs/hour) 
  (A) Batteries 1, E, & H  0.67  78.02 
  (B) Battery 1  0.23  15.70 
  (C) Batteries 1 & E  0.49  46.86 
  (D) Batteries 1 & H  0.50  46.86 
  (E) Batteries E & H  0.79  62.32 
  (F) Battery E  0.79  31.16 
  (G) Battery H  0.79  31.16 
(H) The department and the Indianapolis office of environmental services shall be notified in writing prior to the reliance by Citizens Gas & Coke Utility on an emission limitation other than clause (A).
(I) Gas used for underfiring Battery 1 shall not exceed twenty (20) grains of H2S per one hundred (100) standard cubic feet.
(J) Citizens Gas & Coke Utility shall desulfurize the coke oven gas produced by Batteries 1, E, and H.
(K) Citizens Gas & Coke Utility shall monitor the hydrogen sulfide (H2S) content of the coke oven gas used for underfiring each battery by sampling and analyzing the coke oven gas for H2S content at least once per day. The H2S content of the gas shall be sampled using Determination of Hydrogen Sulphide Content, Cadmium Acetate Method, Method Number DIN 51855 Part 4 (January 1979)*.
(L) Sulfur dioxide emissions in pounds per tons of coal (lbs/ton of coal) and pounds per hour (lbs/hr) shall be calculated using the data on H2S content and organic sulfur content in the coke oven gas. The total sulfur dioxide emissions shall include all sulfur compounds. Citizens Gas & Coke Utility shall submit to the department and the Indianapolis office of environmental services within thirty (30) days of the end of each calendar quarter the calculated sulfur dioxide emission rate in pounds per tons of coal (lbs/ton of coal) and pounds per hour (lbs/hr) for each day during the calendar quarter.
(M) All monitoring and testing data and results shall be recorded, and all records shall be kept for a period of three (3) years. Citizens Gas & Coke Utility shall submit the monitoring and testing records to the department upon request.

*These documents are incorporated by reference. Copies are available for review and copying at the Indiana Department of Environmental Management, Office of Air Quality, Indiana Government Center-North, Tenth Floor, 100 North Senate Avenue, Indianapolis, Indiana 46204.
(Air Pollution Control Division; 326 IAC 7-4-2; filed Aug 28, 1990, 4:50 p.m.: 14 IR 65; filed Feb 9, 1999, 4:22 p.m.: 22 IR 1959; readopted filed Jan 10, 2001, 3:20 p.m.: 24 IR 1477; filed Feb 20, 2007, 3:15 p.m.: 20070321-IR-326050118FRA; filed Sep 2, 2015, 1:50 p.m.: 20150930-IR-326110356FRA)


SECTION 4. 326 IAC 7-4-2.1 IS ADDED TO READ AS FOLLOWS:

326 IAC 7-4-2.1 Marion County sulfur dioxide emission limitations

Authority: IC 13-14-8; IC 13-17-3
Affected: IC 13-15; IC 13-17

Sec. 2.1. (a) On and after January 1, 2017, sources and emission units located in Marion County shall comply with the sulfur dioxide emission limit and other requirements, as follows:
  Source  Emission Unit Description  Emission Limit (lbs/hour) or Other Requirements  Emission Limit (lbs/MMBtu) 
(1)  Citizens  (A) Boiler 11  73.6  0.2 
  Thermal - Perry K  (B) Boiler 13  80.6  0.2 
  Source ID No. 00034  (C) Boiler 14  80.6  0.2 
    (D) Boilers 12, 15, and 16  Burn natural gas   
    (E) Boiler 17  72.6  0.3 
    (F) Boiler 18  72.6  0.3 
(2)  Belmont Advanced Wastewater Treatment Plant Source ID No. 00032  Incinerator 1, Incinerator 2, Incinerator 3, and Incinerator 4  Comply with SO2 limit in 40 CFR 60, Subpart MMMM* or 40 CFR 60, Subpart LLLL*   
(3)  Rolls-Royce  (A) Boiler 0070-58  0.07  0.0015 
  Source ID No.  (B) Boiler 0070-59  0.07  0.0015 
  00311  (C) Boiler 0070-62  0.37  0.0015 
    (D) Boiler 0070-63  0.37  0.0015 
    (E) Boilers 0070-64  Burn natural gas or landfill gas  0.01 
    (F) Boiler 0070-65  Burn natural gas or landfill gas  0.01 
    (G) Generating Turbine 0070-80  Burn natural gas or landfill gas  0.01 
    (H) 2 Gas Turbine Engines 0070-66    0.1 
    (I) 12 Gas Turbine Engines 0070-67    0.05 
    (J) 3 Gas Turbine Engines 0070-68c, 0070-68d, and 0070-68e    0.05 
    (K) 2 Gas Turbine Engines 0070-68a and 0070-68b  Burn natural gas   
    (L) 3 Gas Turbine Engines 0070-69    0.05 
    (M) Three Shack Heaters 0070-70  Burn natural gas   
    (N) Rental Generators    0.0015 
    (O) Engine Test Cells Plant 5    0.05 
    (P) Engine Test Cell Plant 8    0.1 
    (Q) Engine Test Cell N20  18 foot vertical stack, if operating   
    (R) Engine Test Cell N21  20 foot vertical stack, if operating   
    (S) Engine Test Cell N23  30 foot vertical stack, if operating   
    (T) Engine Test Cell N24  20 foot vertical stack, if operating   
(4)  Vertellus  (A) 70K Boiler 70-2722W  18.4  0.20 
  Agriculture and  (B) 30K Boiler 30-2726S  9.8  0.25 
  Nutrition  (C) 28K Boiler 28-186N  9.9  0.27 
  Specialties Source  (D) Boiler CB-70K  Burn natural gas   
  ID No. 00315  (E) BM Furnace BM2724W  1.1  0.05 
    (F) Box Furnace BX2707V  0.8  0.05 
    (G) DAB Furnace 732714  2.8  0.05 
    (H) Born Heater 722804  0.34  0.05 
    (I) Born Heater Furnace BXS2706Q  0.3  0.05 
    (J) EP Furnace EP2729Q  0.15  0.05 
    (K) CB20 CB600-300 Boiler  2.3  0.09 
    (L) 50K CN5-400 Boiler  5.5  0.09 
    (M) BD Furnace BD2714V  0.75  0.05 
    (N) Heater BS2740Q  0.3  0.05 
    (O) Heater BT2728S  0.3  0.05 
    (P) Furnace HW-925.001  12.25  1.25 
    (Q) CS Kettle Born Heater  Burn natural gas   
    (R) CS Still Born Heater  Burn natural gas   
    (S) Born Hot Oil Furnace (Process Heater) Unit 2607T  Burn natural gas   
(5)  Quemetco Source ID No. 00079  WESP Stack  52.0   
(6)  Indianapolis  (A) Boiler 9  Do not operate   
  Power & Light Co. -  (B) Boiler 10  Do not operate   
  Harding Street  (C) Boiler 50  Burn natural gas   
  Generating Station  (D) Boiler 60  Burn natural gas   
  Source ID No.  (E) Boiler 70  Burn natural gas   
  00033  (F) Gas Turbine 1  29.9  0.1 
    (G) Gas Turbine 2  29.9  0.1 
    (H) Gas Turbine 4  87.5  0.1 
    (I) Gas Turbine 5  86.7  0.1 
    (J) Gas Turbine 6  Burn natural gas   
    (K) Emergency Generator  500 hour calendar year operating limit   

(b) Compliance with the emission limit in subsection (a)(5) shall be determined by using quality assured hourly average continuous emission monitoring system data.

*These documents are incorporated by reference. Copies may be obtained from the Government Printing Office, 732 North Capitol Street NW, Washington, D.C. 20401 or are available for review and copying at the Indiana Department of Environmental Management, Office of Legal Counsel, Indiana Government Center North, Thirteenth Floor, 100 North Senate Avenue, Indianapolis, Indiana 46204.
(Air Pollution Control Division; 326 IAC 7-4-2.1; filed Sep 2, 2015, 1:50 p.m.: 20150930-IR-326110356FRA)


SECTION 5. 326 IAC 7-4-3 IS AMENDED TO READ AS FOLLOWS:

326 IAC 7-4-3 Vigo County sulfur dioxide emission limitations before January 1, 2017

Authority: IC 13-14-8; IC 13-17-3-4

Sec. 3. The following Before January 1, 2017, sources and facilities emission units located in Vigo County shall comply with the sulfur dioxide emission limitations in pounds per million Btu, unless otherwise specified, and other requirements, as follows:
  Source  Facility Emission Unit Description  Emission Limitations 
  (1) Alcan Rolled Products Co.  Sol Oil Boiler  0.51 
    Foil Mill Boiler  0.51 
    Oil Farm Boiler  0.51 
    #2 Melter  1.60 
    #3 Melter  1.60 
    #4 Melter  1.60 
    #5 Melter  1.60 
    #6 Melter  1.60 
    #7 Melter  1.60 
    #53 Annealing Furnaces  1.60 
  (2) Bemis  Boiler  0.51 
  (3) CBS  #1 WH CB200-200  0.51 
    #2 WH CB200-200  0.51 
    #1 HC CB293-100  0.51 
    #2 HC CB M & W 4000  0.51 
    #3 HC CB M & W 4000  0.51 
    #1 BP Springfield  0.51 
  (4) CF Industries  Process Murray Boiler 1  0.52 
    Process Murray Boilers 2 and 3  0.52 
  (5) (1) SONY Digital Audio Disc  (A) #1 Kewanee Boiler  0.36 
  Source ID No. 00032  (B) #2 Kewanee Boiler  0.36 
  (6) Doxsee Foods Corp.  Boiler  2.62 
  (7) General Housewares  Boiler 1A Ladd  6.00 
    Boiler 2A Combustion Eng.  6.00 
    #5 Enamel Furnace Radiant Tube  0.51 
    #6 Enamel Furnace Muffle  0.51 
  (8) Hercules, Inc. (2) Taghleef  (A) Murray Iron Works Boiler A  0.51 
  Industries Source ID No. 00045  (B) Murray Iron Works Boiler B  0.51 
    (C) Clayton Boiler (Standby)  0.51 
    (D) Nebraska Boiler  0.51 
  (9) Indiana State University  #2 Voight Boiler  5.64 
    #3 Voight Boiler  5.64 
    #5 B & W Boiler  5.64 
    #4 Murray Boiler  0.37 
  (10) J.I. Case  No. 1 Riley Boiler  4.74 
    No. 2 Riley Boiler  4.74 
  (11) Pfizer  Boiler 8  3.01 
  (12) Pillsbury (Terre Haute)  Boiler B  0.36 
    Boiler C  2.62 
    Boiler D  0.36 
  (13) Pitman-Moore  #9, #10, and #15 Boilers  4.58 
    #16 Boiler  0.36 
    East Plant Boiler  0.36 
  (14) Public Service Indiana (3) Duke Energy Wabash River Source ID No. 00021  Boilers 1, 2, 3, 4, 5, and 6  4.04 
  (15) Rose-Hulman  #1 Voight Boiler  2.26 
    #2 Cleaver Brooks Boiler  0.51 
    #4 Cleaver Brooks Boiler  0.51 
  (16) St. Mary's Sisters of Providence  #2 Voight Boiler  3.84 
    #3 B & N Boiler  3.84 
    #5 B & N Boiler  3.84 
    #7 Voight Boiler  3.84 
    #8 Voight Boiler  3.84 
  (17) Snacktime Company  #1 Boiler  0.52 
    #12 Boiler  0.52 
    #2, #3, #4, and #6  0.52 
    Fryer Oil Heaters 
  (18) Terre Haute Coke and Carbon  2 CB Boilers  1.79 
    2 Standby Boilers  4.55 
    No. 1 CB Underfire Stack  0.63 
    No. 2 CB Underfire Stack  0.63 
  (19) (4) Terre Haute Regional Hospital  (A) #1 Boiler  0.45 
  Source ID No. 00046  (B) (New) #2 Boiler  0.45 
  (20) (5) Union Hospital Energy Co.  2 Keeler Boilers  0.36 
  Source ID No. 00047  3 Cleaver Brooks Boilers  0.36 
  (21) U.S. Penitentiary  #1, #2, and #3 Boilers  0.51 
    2 Honor Farm Boilers  0.51 
  (22) Wabash Fibre Box  Cleaver Brooks Boiler  2.36 
  (23) Wabash Products Co.  Boiler  natural gas only 
  (24) Western Tar  Tar Division, Boiler A  0.36 
    Tar Division, Boiler B  0.36 
    Wood Division, Boiler A  0.36 
    Wood Division, Boiler B  0.36 
    Tar Division, Process Still  0.36 
  (25) Weston Paper  B-1 and B-4 Boilers  4.09 
    B-5 Warehouse Boiler  2.62  
(Air Pollution Control Division; 326 IAC 7-4-3; filed Aug 28, 1990, 4:50 p.m.: 14 IR 70; readopted filed Jan 10, 2001, 3:20 p.m.: 24 IR 1477; filed Aug 31, 2004, 2:30 p.m.: 28 IR 117; filed Sep 2, 2015, 1:50 p.m.: 20150930-IR-326110356FRA)


SECTION 6. 326 IAC 7-4-3.1 IS ADDED TO READ AS FOLLOWS:

326 IAC 7-4-3.1 Vigo County sulfur dioxide emission limitations

Authority: IC 13-14-8; IC 13-17-3
Affected: IC 13-15; IC 13-17

Sec. 3.1. (a) On and after January 1, 2017, sources and emission units located in Vigo County shall comply with the sulfur dioxide emission limits and other requirements, as follows:
  Source  Emission Unit Description  Emission Limit (lbs/hour) or Other Requirements  Emission Limit (lbs/MMBtu) 
(1)  Wabash River Combined Cycle Source ID No. 00147  Combustion Turbine Unit 1A  333.76  0.195 
(2)  sgSolutions  (A) Tail Gas Incinerator Stack EP1  230.6   
  Source ID No. 00091  (B) Process Flare Unit 2  500 hour calendar year operating limit on coal/syngas   
(3)  SONY Digital  (A) #1 Kewanee Boiler    0.05 
  Audio Disc  (B) #2 Kewanee Boiler    0.05 
  Source ID No. 00032  (C) Unit 3 Burnham Boiler    0.05 
    (D) Unit 4 Burnham Boiler    0.05 
    (E) Unit 5 Superior Boiler    0.05 
    (F) Unit 6 Superior Boiler    0.05 
    (G) Unit 18 Boiler    0.05 
(4)  Taghleef Industries  (A) Clayton Boiler (Standby)  0.03  0.0015 
  Source ID No. 00045  (B) Nebraska Boiler  0.05  0.0015 
    (C) Nebraska-D Boiler  Burn natural gas   
(5)  Terre Haute  (A) #1 Boiler    0.45 
  Regional Hospital Source ID No. 00046  (B) New #2 Boiler    0.45 
(6)  Union Hospital Source ID No. 00047  2 Keeler Boilers    0.36 
(7)  Duke Energy -  (A) Boiler 6  1,499.5  0.5 
  Wabash River Generating Station Source ID No. 00021  (B) Diesel Generators 7A, 7B, and 7C  500 hour calendar year operating limit (each)  0.05 

(b) Compliance with the emission limit in subsection (a)(1) shall be determined by using quality assured hourly average continuous emission monitoring system data.

(c) Compliance with the emission limit in subsection (a)(2)(A) shall be determined by calculating the thirty (30) unit operating day rolling arithmetic average emission rate at the end of each unit operating day using all of the quality assured hourly average continuous emission monitoring system data for the previous thirty (30) unit operating days. Unit operating day means a twenty-four (24) hour period that begins at midnight and ends the following midnight during which the unit is operated. It is not necessary for the unit to be operating the entire twenty-four (24) hour period.
(Air Pollution Control Division; 326 IAC 7-4-3.1; filed Sep 2, 2015, 1:50 p.m.: 20150930-IR-326110356FRA)


SECTION 7. 326 IAC 7-4-11 IS AMENDED TO READ AS FOLLOWS:

326 IAC 7-4-11 Morgan County sulfur dioxide emission limitations before January 1, 2017

Authority: IC 13-14-8; IC 13-17-3
Affected: IC 13-15; IC 13-17

Sec. 11. Before January 1, 2017, Indianapolis Power and & Light Company (IPL) Pritchard Eagle Valley Generating Station, Source ID No. 00004, shall comply with the sulfur dioxide emission limitations in pounds per million Btu and other requirements as follows:
  Facility Emission Unit Description  Emission Limitations 
  (1) Units 1 and 2  0.37 each 
  (2) Units 3, 4, 5, and 6 on and before September 30, 1990  6.0 each 
  Unit 3 after September 30, 1990  0.37 
  (3) Units 4, 5, and 6 after September 30, 1990  3.04 each 
(3) (4) As an exception to the emission limitations specified in subdivision subdivisions (2) and (3), after September 30, 1990, at any time in which IPL burns coal on Unit 3, sulfur dioxide emissions from Units 3, 4, 5, and 6 shall be limited to two and fifty-seven hundredths (2.57) pounds per million Btu each.
(4) Prior to October 31, 1989, IPL shall modify (5) The two (2) stacks serving Units 3, 4, 5, and 6 to increase the height of each stack to shall be at least two hundred and eighty-one (281) feet above grade.
(5) Prior to February 28, 1989, IPL shall submit completed engineering plans and drawings of flue gas conditioning systems for Units 4 and 5 to the department. Prior to May 31, 1990, IPL shall complete installation of flue gas conditioning systems for Units 4 and 5.
(6) After September 30, 1990, on a day for which Unit 3 does not burn any coal, the limitations in subdivision subdivisions (2) and (3) are in effect, and compliance shall be determined as specified in 326 IAC 7-2-1(c). 326 IAC 7-2-1(d).
(7) After September 30, 1990, on a day for which Unit 3 burns any coal, the limitations in subdivision (3) (4) are in effect. As an exception to the requirements of 326 IAC 7-2-1(c)(1) 326 IAC 7-2-1(d)(1) on a day for which Unit 3 burns any coal, if the thirty (30) day rolling weighted average for any unit is above two and fifty-seven hundredths (2.57) pounds per million Btu, then 326 IAC 7-2-1(c)(1) 326 IAC 7-2-1(d)(1) does not apply, and the daily average emission rate for that unit for that day shall not exceed two and fifty-seven hundredths (2.57) pounds per million Btu.
(8) After September 30, 1990, for the purposes of determining compliance under 326 IAC 7-2-1(b), 326 IAC 7-2-1(h)(1), stack tests performed on Units 3, 4, 5, and 6 shall demonstrate compliance with the most stringent set of limits in effect at any time during the day prior to or during the test based on the Unit 3 operating status and fuel type as indicated by the log maintained pursuant to subdivision (9).
(9) After September 30, 1990, IPL shall maintain and make available to the department upon request a log of the operating status and fuel type used for Unit 3. In addition, in the quarterly report required by 326 IAC 7-2-1(a), 326 IAC 7-2-1(c), IPL shall submit to the department a daily summary indicating fuel type for Unit 3, and, for days on which Unit 3 burned any coal and any thirty (30) day rolling weighted average was greater than two and fifty-seven hundredths (2.57) pounds per million Btu, IPL shall submit to the department the daily average sulfur content, heat content, and sulfur dioxide emission rate for Units 3, 4, 5, and 6.
(Air Pollution Control Division; 326 IAC 7-4-11; filed Aug 28, 1990, 4:50 p.m.: 14 IR 76; readopted filed Jan 10, 2001, 3:20 p.m.: 24 IR 1477; filed Sep 2, 2015, 1:50 p.m.: 20150930-IR-326110356FRA)


SECTION 8. 326 IAC 7-4-11.1 IS ADDED TO READ AS FOLLOWS:

326 IAC 7-4-11.1 Morgan County sulfur dioxide emission limitations

Authority: IC 13-14-8; IC 13-17-3
Affected: IC 13-15; IC 13-17

Sec. 11.1. (a) On and after January 1, 2017, sources and emission units located in Morgan County shall comply with the sulfur dioxide emission limits and other requirements, as follows:
  Source  Emission Unit Description  Emission Limit or Other Requirements  Emission Limit (lbs/MMBtu) 
(1)  Indianapolis Power & Light Company (IPL)  (A) Combined Cycle Combustion Turbine 1 including duct burners  Burn natural gas   
  - Eagle Valley Generating Station  (B) Combined Cycle Combustion Turbine 2 including duct burners  Burn natural gas   
  Source ID No. 00004  (C) Auxiliary Boiler  Burn natural gas   
    (D) Dew Point Heater  Burn natural gas   
(2)  Hydraulic Press Brick  (A) Kiln 3  Do not operate   
  Company (HPB) Source ID No. 00007  (B) Kiln 4  Minimum control efficiency of 50% or 2.5 lbs/MMBtu, whichever is less stringent  6.0 
    (C) Kiln 5  Minimum control efficiency of 50% or 2.5 lbs/MMBtu, whichever is less stringent  6.0 

(b) HPB shall comply with the sulfur dioxide emission limits in subsection (a)(2) as follows:
(1) The emission limit applies to sulfur dioxide emissions from both the combustion of coal and the processing of shale.
(2) Monthly fuel sampling and analysis data shall be collected according to 326 IAC 7-2-1 for both coal and shale.
(3) HPB shall install and operate a limestone injection system to control sulfur dioxide emissions from Kiln 4 and Kiln 5.
(4) Compliance with the control efficiency limit in subsection (a)(2) shall be based on measured sulfur content in the shale and fuel compared to the outlet SO2 concentration determined by a stack test pursuant to 326 IAC 3-6. The shale and fuel sulfur content measurements for this purpose shall reflect a representative sample of the material fed into the kiln during each run of the stack test.
(Air Pollution Control Division; 326 IAC 7-4-11.1; filed Sep 2, 2015, 1:50 p.m.: 20150930-IR-326110356FRA)


SECTION 9. 326 IAC 7-4-15 IS ADDED TO READ AS FOLLOWS:

326 IAC 7-4-15 Pike County sulfur dioxide emission limitations

Authority: IC 13-14-8; IC 13-17-3
Affected: IC 13-15; IC 13-17

Sec. 15. (a) On and after January 1, 2017, sources and emission units located in Pike County shall comply with the sulfur dioxide emission limits and other requirements, as follows:
  Source  Emission Unit Description  Emission Limit (lbs/hour) or Other Requirements  Emission Limit (lbs/MMBtu) 
(1)  Indianapolis Power &  (A) Unit 1  330.0  0.15 
  Light - Petersburg  (B) Unit 2  621.6  0.15 
  Generating Station  (C) Unit 3  2,049.8  0.37 
  Source ID No.  (D) Unit 4  1,942.5  0.35 
  00002  (E) Diesel Generators PB-2, PB-3, and PB-4  500 hour calendar year operating limit (each)   
(2)  Hoosier Energy - Ratts  (A) Boiler 1  58  0.05 
  Source ID No. 00001  (B) Boiler 2  58  0.05 
    (C) No. 2 Auxiliary Boiler  1  0.05 

(b) Compliance with the emission limits in subsection (a) shall be determined by using quality assured hourly average continuous emission monitoring system data, except as allowed under subsection (c).

(c) As an alternative to the emission limits in subsection (a)(1)(A) though (a)(1)(D), Indianapolis Power & Light - Petersburg Generating Station may comply with the following:
  Emission Unit Description  Emission Limit (lbs/hour - 30 day rolling average)  Emission Limit (lbs/MMBtu - 30 day rolling average) 
(1)  Unit 1  263.0  0.12 
(2)  Unit 2  495.4  0.12 
(3)  Unit 3  1,633.7  0.29 
(4)  Unit 4  1,548.2  0.28 

(d) Compliance with the emission limits in subsection (c) shall be determined by calculating the thirty (30) boiler operating day rolling arithmetic average emission rate at the end of each boiler operating day using all of the quality assured hourly average continuous emission monitoring system data for the previous thirty (30) boiler operating days. Boiler operating day means a twenty-four (24) hour period that begins at midnight and ends the following midnight during which any fuel is combusted at any time in the boiler. It is not necessary for the fuel to be combusted the entire twenty-four (24) hour period.

(e) Indianapolis Power & Light shall notify the department prior to the compliance date to indicate if compliance for Units 1 through 4 will be determined using the emission limits in subsection (a) or subsection (c) and prior to switching from compliance with the set of emission limits in subsection (a) to subsection (c) or from subsection (c) to subsection (a). Indianapolis Power & Light may not switch between complying with the one (1) hour average limits in subsection (a) and the thirty (30) day rolling average limits in subsection (c) unless Indianapolis Power & Light continues to show compliance with the one (1) hour average limit for each boiler until the first thirty (30) boiler operating day rolling arithmetic average emission rate is calculated.
(Air Pollution Control Division; 326 IAC 7-4-15; filed Sep 2, 2015, 1:50 p.m.: 20150930-IR-326110356FRA)


SECTION 10. THE FOLLOWING ARE REPEALED: 326 IAC 7-4-2; 326 IAC 7-4-3; 326 IAC 7-4-11.

SECTION 11. SECTION 10 of this document takes effect January 1, 2017.

LSA Document #11-356(F)
Proposed Rule: 20150422-IR-326110356PRA
Hearing Held: July 8, 2015
Approved by Attorney General: August 18, 2015
Approved by Governor: September 2, 2015
Filed with Publisher: September 2, 2015, 1:50 p.m.
Documents Incorporated by Reference: None Received by Publisher
Small Business Regulatory Coordinator: Jessica Faust-Hamblin, IDEM Small Business Regulatory Coordinator, Indiana Government Center North 1225, 100 North Senate Avenue, Indianapolis, IN 46204-2251, (317) 232-8172 or (800) 988-7901, ctap@idem.in.gov
Small Business Assistance Program Ombudsman: Steven N. Howell, IDEM Small Business Assistance Program Ombudsman, Indiana Government Center North 1301, 100 North Senate Avenue, Indianapolis, IN 46204-2251, (317) 232-8587 or (800) 451-6027, snhowell@idem.in.gov

Posted: 09/30/2015 by Legislative Services Agency

DIN: 20150930-IR-326110356FRA
Composed: Apr 24,2024 6:36:57PM EDT
A PDF version of this document.