TITLE 326 AIR POLLUTION CONTROL DIVISION

The Indiana Department of Environmental Management (IDEM) has developed draft rule language for amendments to 326 IAC 7 concerning sulfur dioxide (SO₂) emission limitations to implement the new 1-hour SO₂ National Ambient Air Quality Standard (NAAQS). IDEM is proposing to amend 326 IAC 7-4-2, 326 IAC 7-4-3, and 326 IAC 7-4-11 to update current limits until the proposed new limits take effect. New rules will be added at 326 IAC 7-1.1-3 (compliance date) and 326 IAC 7-4-2.1, 326 IAC 7-4-3.1, 326 IAC 7-4-11.1, and 326 IAC 7-4-15 to add emission limits for the 1-hour SO₂ NAAQS. Rules at 326 IAC 7-4-2, 326 IAC 7-4-3, and 326 IAC 7-4-11 will be repealed as of January 1, 2017. By this notice, IDEM is soliciting public comment on the draft rule language. IDEM seeks comment on the affected citations listed and any other provisions of Title 326 that may be affected by this rulemaking.

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).

The United States Environmental Protection Agency (U.S. EPA) issued a revised primary NAAQS for SO₂ on June 22, 2010, in the Federal Register (FR) (75 FR 35520). The largest sources of SO₂ emissions are from fossil fuel combustion at power plants and other industrial facilities. U.S. EPA first established standards for SO₂ in 1971. U.S. EPA also set a 3-hour average secondary standard at 500 ppb to protect public welfare. Based on new studies, U.S. EPA determined that the 1971 standards are not sufficient to protect public health with an adequate margin of safety. Therefore, with the final rule published on June 22, 2010, U.S. EPA strengthened the NAAQS for SO₂ by establishing a new 1-hour standard at a level of 75 ppb to reduce human exposure to high short-term (five minutes to 24 hours) concentrations of SO₂. U.S. EPA revoked the two existing primary standards (0.14 ppm 24-hour standard and 0.03 ppm annual average standard) and kept the secondary standard of 0.5 ppm 3-hour average. U.S. EPA also set a new form for the standard; a 3-year average of the 99th percentile of the annual distribution of daily maximum 1-hour average concentrations.

Final designations for nonattainment areas based on monitoring data through 2012 were made on August 5, 2013 (78 FR 47191). This rulemaking will revise or add emission limitations in 326 IAC 7 to address state implementation plan (SIP) development requirements for counties with townships designated as nonattainment for the 1-hour standard. The SIP for the currently designated nonattainment areas is due to U.S. EPA on April 6, 2015. Federal law does not detail the exact emission controls needed to address nonattainment counties, but emission limitations must demonstrate compliance with the 1-hour SO₂ NAAQS. U.S. EPA will determine designations for additional areas based on additional monitoring and/or modeling at a later date. IDEM will also amend the current emission limitations in 326 IAC 7 for Marion County, Morgan County, and Vigo County, to address the numerous sources that are now closed. Townships designated as nonattainment on August 5, 2013, are as follows:

Marion County (Wayne, Center, Perry)

Morgan County (Clay, Washington)

Daviess County (Veale)

Pike County (Washington)

Vigo County (Fayette, Harrison)

Emission limits in 326 IAC 7 are being revised or added for sources located in counties currently designated as nonattainment: Marion County, Morgan County, Pike County, and Vigo County. There are no SO₂ sources in Daviess County. Sources are being included in the draft rule language in the proposed new rules at 326 IAC 7-4-2.1, 326 IAC 7-4-3.1, 326 IAC 7-4-11.1, and 326 IAC 7-4-15 based on guidance published by U.S. EPA on April 23, 2014 ("Guidance for 1-Hour SO₂ Nonattainment Area SIP Submissions"). Sources already included in the current SIP and located in 1-hour nonattainment areas are included in the new rule. Sources may be removed or added to this rule based on additional information. Sources that model attainment based on allowable emissions are not required to be included in the rule if the current limits are permanent and enforceable. IDEM is not proposing to include diesel emergency generators in the source specific listing as these units are intermittent and are not required to be included. For some sources additional discussion with U.S. EPA will be needed to determine what emission units are included in the rule. Additional analysis may show that a source is or is not contributing to an attainment violation and the proposed rule will be revised accordingly during the rulemaking. The proposed emission limits and modeling protocol will be provided to U.S. EPA for review during the rulemaking process.

The current limits in 326 IAC 7-4-2 (Marion County), 326 IAC 7-4-3 (Vigo County), and 326 IAC 7-4-11 (Morgan County) will remain effective through December 31, 2016. The new limits to implement the 1-hour NAAQS 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 will take effect on January 1, 2017.

If sources are permitted to use No. 2 distillate fuel oil or No. 6 residual fuel oil as a back-up or alternative fuel source for a primarily natural gas-fueled boiler, the current general limits at 326 IAC 7-1.1-2 are used in the modeling, unless a lower source specific limit is listed in the rule. Lower source specific limits are listed 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 when needed for a particular source to show attainment with the new standard. The use of the general limits in 326 IAC 7-1.1-2 could over predict the health impact of the emissions from these boilers since most sources now use low sulfur fuel and actual emissions from the source are much lower. Low sulfur (0.05% sulfur or 500 ppm) fuel has been required for on-highway use for some time and ultra-low sulfur diesel (0.0015% or 15 ppm) fuel is now required for on-highway use. Many sources are burning fuel oil with much lower sulfur content because that is, in most instances, the only fuel available.

The draft rule language does not change the current compliance demonstration and reporting requirements for fossil fuel combustion sources contained in 326 IAC 3-7-2, 326 IAC 3-7-4, and 326 IAC 7-2-1. Currently, larger coal combustion sources demonstrate compliance with the current limits on a 30-day rolling average and smaller coal combustion sources demonstrate compliance using a calendar month average unless a shorter averaging time is specified for a source. For all other combustion sources, including units firing fuel oil, compliance is determined using a calendar month average. For many sources, compliance with sulfur content in fuel oil is based on vendor certification of sulfur content. The sulfur content of the fuel oil does not vary from hour to hour. Procedures for coal sulfur content with coal sampling and analysis are contained in 326 IAC 3-7-2, and procedures for determining sulfur content by fuel oil sampling are contained in 326 IAC 3-7-4 with analysis by the source or vendor certification. Sources can also demonstrate compliance using SO₂ continuous emission monitoring systems (CEMS) or stack testing.

IDEM is obligated to develop 1-hour averaging periods for limits on emission units that have continuous emissions monitoring systems (CEMS). U.S. EPA issued a memorandum, "Guidance for 1-Hour SO₂ Nonattainment Area SIP Submissions", on April 23, 2014. This guidance gives example determinations of longer term averaging for emission limits. The proposed emission limits in this Second Notice of Public Comment Period are based on a 1-hour averaging time frame. If sources are interested in longer term averaging, additional information to support a longer term average can be submitted to the department for consideration at preliminary adoption. IDEM has received a request from Indianapolis Power and Light (IPL) to allow for a 30-day rolling average limit as an alternative to the 1-hour limit for IPL Petersburg Generating Station. Their request, which is based on a data analysis as outlined in the U.S. EPA 1-hour SO₂ nonattainment area guidance, provides for an adjustment to 79.7% of the 1-hour limit. The proposed alternative 30-day rolling average limits are included in the draft rule language for public comment. Many non-combustion related sources have 3-hour or 24-hour averaging times already established in current permit based limits, or are currently required to demonstrate compliance based on a stack test and not CEMS. Unless specifically noted in the proposed rule language, CEMS are not required to demonstrate compliance with the new 1-hour SO₂ nonattainment area emission limits. CEMS are required to be operated in accordance with the procedures in 326 IAC 3-5 that are based on performance specifications under 40 CFR 60. Many sources are also subject to CEMS requirements under 40 CFR 75. IDEM is requesting comment on any data analysis issues (such as data substitution) that need to be made consistent in order to show compliance with the proposed SO₂ limits 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. All sources required to have CEMS are also Title V operating permit sources subject to extensive record keeping and reporting under the Title V operating permit rules at 326 IAC 2-7. IDEM is still discussing compliance demonstration requirements with affected sources and U.S. EPA; requirements are subject to change by final adoption.

For most units included in the rule there are two limits. The pound per hour (lb/hr) form of the limit provides a cap on emissions independent of the size of the unit and a pound per million British thermal units (lb/mmBtu) limit restricts the sulfur content of the fuel independent of load capacity. In accordance with U.S. EPA guidance, emission units were modeled at design capacity (100 percent load). If a unit were to operate at reduced load to meet the lb/hr limit without a corresponding lb/mmbtu limit there could be an impact on NAAQS that was not addressed in the SIP modeling. IDEM is not proposing a lb/hr limit on small boilers that are being carried over from the current SIP to the new 1-hour SIP, for example, both of the hospitals in Vigo County. These limits are being retained in the SIP because they are already there, not because they are needed to show attainment with the new 1-hour NAAQS. Compliance for smaller oil-fired boilers in the source specific listing is similar to the general limits provided under 326 IAC 7-1.1-2.

Since the current SIP rule limits will continue to be in place until December 31, 2016, IDEM is proposing to update the current limits, if needed, as many of the sources listed in the rule have since closed or the emission unit listed in the rule is no longer operating. In Marion County and Vigo County there are numerous sources that will no longer be listed in the source specific emission limitations portion of the rule at 326 IAC 7-4. IDEM is also adding the source identification number (source ID No.) to aid in future identification of sources included in the rule.

IDEM seeks comments from interested parties on this rulemaking. IDEM will continue to work with sources to refine the emission limits, modeling, and compliance provisions for each source as part of the SIP development process so that emission limits will be based on what is necessary for each area to attain the standard.

No element of the draft rule imposes either a restriction or a requirement on persons to whom the draft rule applies that is not imposed under federal law.

This rulemaking is imposed by federal law and will not have a fiscal impact beyond what is required by federal law. At this time, IDEM cannot accurately ascertain the fiscal impact of the federal requirements this rulemaking is addressing. The fiscal impact for each affected source will vary depending on the final emission limitations and monitoring requirements for that source.

At this time, no work group is planned for the rulemaking. IDEM will meet with affected sources on an as needed basis. If you feel that a workgroup or other informal discussion on the rule is appropriate, please contact Susan Bem, Rules Development Branch, Office of Legal Counsel at (317) 233-5697 or (800) 451-6027 (in Indiana).

IDEM requested public comment from June 29, 2011, through July 29, 2011, on alternative ways to achieve the purpose of the rule and suggestions for the development of draft rule language. IDEM received comments from the following parties by the comment period deadline:

Save the Dunes (SD)

Purdue University (PU)

Citizen's Thermal (CT)

Indiana Energy Association (IEA)

B Paul Consulting (BPC)

Following is a summary of the comments received and IDEM's responses thereto:

Comment: How is IDEM proposing to adjust the monitoring network in northwest Indiana as a result of the new standard? (SD)

Response: The federal rules at 40 CFR Part 58, Appendix D, 4.4, detail the requirements for SO₂ monitoring. The monitoring requirements for the new SO₂ standard are met by the current monitoring network for the entire state, including northwest Indiana. A detailed evaluation, area by area, is included in the Indiana 2015 Ambient Air Monitoring Network Plan. IDEM proposes discontinuing the Indianapolis – E. 16^th St. monitor as the design values for the previous five years have been less than 80% (60 ppb) of the NAAQS. This document is available at: http://www.in.gov/idem/airquality/2389.htm.

Comment: In the First Notice of Public Comment Period, it states that based on preliminary analysis, nine counties are preliminarily identified as being in noncompliance. Which are these? Which one county is contributing to a monitored violation in an adjacent county? (SD)

Response: The First Notice of Public Comment Period identified nine counties that currently have monitors measuring ambient concentrations above the standard: Daviess, Floyd, Fountain, Gibson, Marion, Morgan, Pike, Vigo, and Wayne. On May 11, 2011, Indiana recommended these counties be classified as nonattainment. Indiana also recommended Vermillion County be classified as nonattainment based upon the contribution of a source in that county to the monitor in Fountain County. Based on additional analysis in early 2012, Indiana recommended townships within five of the nine counties, rather than the entire county, to be classified as nonattainment based on the monitored violations and location of sources contributing to the monitored violations. Final designations for nonattainment based on monitoring data through 2012 were made on August 5, 2013 (78 FR 47191). Townships designated as nonattainment in Indiana are:

Marion County (Wayne, Center, Perry)

Morgan County (Clay, Washington)

Daviess County (Veale)

Pike County (Washington)

Vigo County (Fayette, Harrison).

Comment: What is the modeling process being used by IDEM to evaluate how counties are designated? (SD)

Response: Modeling was not used to determine the designation status of the counties in Indiana. Designations were based upon monitored values and locations of major sources.

Comment: IDEM should revise the SO₂ monitoring requirements in 326 IAC 7 to address monitoring requirements for the new standard. (SD)

Comment: The existing SO₂ ambient monitoring requirements in 326 IAC 7-3 are sufficient for the purposes of the proposed rule. (IEA)

Response: IDEM is not proposing to make amendments to the ambient monitoring requirements at 326 IAC 7-3-1. Federal rules do not require states to amend the ambient monitoring requirements for large SO₂ emitting sources. Federal rules at 40 CFR 58 for monitoring networks apply to state agencies not individual sources.

Comment: The commenter supports Alternative #2 in the First Notice of Public Comment Period and suggests that IDEM explore ways to accommodate the new standard by using the existing Title V permitting program instead of 326 IAC 7. Allowing facility level changes to be made through Title V would expedite the process significantly and ease the burden on sources for emission limit adjustments. (PU) (CT)

Response: The emission limits used to demonstrate compliance with the new standard must be permanent and enforceable to meet SIP requirements. Title V permits are not permanent because they expire and cannot be used as an alternative to rulemaking.

Comment: A workgroup should be established to better facilitate communication among stakeholders. (PU)(CT)

Response: At this time, IDEM is proposing to work with affected sources on an individual basis to discuss attainment strategies for each source. If necessary, IDEM will hold meetings with all sources or groups of sources and interested parties as the rulemaking progresses.

Comment: There are numerous new regulations that will require very stringent SO₂ emission limitations and will result in reduction of levels of SO₂ in the air. IDEM and the regulated community should not expend considerable and limited resources to develop complex attainment plans for units that are near retirement. Also, actual electric generating unit (EGU) SO₂ emissions are now substantially less than permitted allowable emissions and even more reductions are required in the near future. IDEM should acknowledge all Clean Air Act obligations before evaluating EGU sector compliance with the 2017 deadline. IDEM should work directly with each EGU to evaluate future SO₂ emission reduction requirements before imposing additional regulations. IDEM should also establish practical modeling protocols and local technical analyses when developing the attainment plan. (IEA)

Response: IDEM understands the concerns of the sources and will work directly with each affected source to develop an attainment plan. IDEM has brought up many concerns and issues with implementing this new standard to U.S. EPA and will continue to work with U.S. EPA and sources to develop a workable approach. Modeling conducted to support the proposed emission limits considers future compliance strategies for each affected source.

Comment: The proposed rule will establish new or revised SO₂ limits for numerous sources and will establish new or revised compliance monitoring requirements to ensure that sources can demonstrate compliance with the new or revised emission limits. This could require sources to invest in expensive emission control systems, retire existing operations, switch fuels, reconfigure stacks, or accept operational limits that restrict the source's growth and flexibility. Compliance monitoring can also be expensive. A shorter averaging period (one hour) may also be required. IDEM should carefully craft SO₂ emission limits of appropriate periods. There is precedent in previous attainment plans where IDEM has established, and U.S. EPA has approved, emission limits where compliance is determined using longer compliance determination period (for example, monthly) when the air quality standard is of a shorter duration. Existing SO₂ SIP requirements in place in Indiana were driven primarily by the need to comply with a 24-hour air quality standard, and the approved SIPs allow compliance determinations based on monthly fuel analysis. Likewise, VOC RACT rules, which were originally aimed at achieving a 1-hour ozone air quality standard, include monthly compliance determinations instead of shorter time periods. SO₂ CEMS should not be required. (BPC)

Response: IDEM understands the concerns with the averaging time and is closely following development of U.S. EPA guidance on this issue. U.S. EPA issued a memorandum, "Guidance for 1-Hour SO2 Nonattainment Area SIP Submissions" on April 23, 2014. This guidance gives example determinations of longer term averaging for emission limits. The proposed emission limits in this Second Notice of Public Comment Period are based on a 1-hour averaging timeframe. If sources are interested in longer term averaging, additional information to support a longer term average can be submitted to the department for consideration during preliminary adoption.

IDEM requested public comment from September 25, 2013, through October 25, 2013, on alternative ways to achieve the purpose of the rule and suggestions for the development of draft rule language. IDEM received comments from the following party by the comment period deadline:

B Paul Consulting (BPC)

Following is a summary of the comments received and IDEM's responses thereto:

Comment: Generally, the SO₂ Project (a coalition of companies and organizations in Indiana) supports IDEM's approach in developing SO₂ regulations for inclusion in Indiana's SO₂ SIP. At the current time, IDEM is obligated to develop SIPs only for those facilities located in the SO₂ nonattainment areas, and the strategy IDEM announced in the September 25, 2013, Indiana Register notices falls within that general obligation. The SO₂ Project agrees with IDEM that it is premature to begin developing SO₂ SIP requirements for sources in areas that have not been designated nonattainment. The process for sources in the undesignated areas should not begin until U.S. EPA has published rules to establish implementation requirements for SO₂ SIPs in these areas. (BPC)

Response: IDEM agrees and has only included emission limits for areas currently designated nonattainment. A separate rulemaking will be started if additional areas are designated nonattainment based on modeling or new monitoring data.

Comment: The commenter urges IDEM to consider the unique and complex technical issues that a NAAQS with a 1-hour averaging period presents. The accuracy of computer modeling for a 1-hour air quality standard has been shown to be questionable. It appears the conservative assumptions used in the AERMOD model are exacerbated when applied to short term modeling results. IDEM should move carefully in establishing emission limits derived from computer models. Furthermore, IDEM must take into consideration the statistical form of the 1-hour SO₂ NAAQS when establishing emission limits for sources. IDEM should avoid establishing limits with 1-hour averaging periods because such emission limits greatly reduce a source's flexibility and ignore the natural variability that can occur with sulfur containing fuels. (BPC)

Response: IDEM is obligated to develop 1-hour averaging periods for limits on emission units that have continuous emissions monitoring systems (CEMS). U.S. EPA issued a memorandum, "Guidance for 1-Hour SO₂ Nonattainment Area SIP Submissions" on April 23, 2014. This guidance gives example determinations of longer term averaging for emission limits. The proposed emission limits in this Second Notice of Public Comment Period are based on a 1-hour averaging timeframe. If sources are interested in longer term averaging, additional information to support a longer term average can be submitted to the department for consideration during preliminary adoption.

This notice requests the submission of comments on the draft rule language, including suggestions for specific revisions to language to be contained in the draft rule. Comments may be submitted in one of the following ways:

(1) By mail or common carrier to the following address:

LSA Document #11-356 1-Hour SO₂ Rule

Susan Bem

Rules Development Branch

Office of Legal Counsel

Indiana Department of Environmental Management

100 North Senate Avenue

Indianapolis, IN 46204-2251

(2) By facsimile to (317) 233-5970. Please confirm the timely receipt of faxed comments by calling the Rules Development Branch at (317) 232-8922.

(3) By electronic mail to sbem@idem.in.gov. To confirm timely delivery of submitted comments, please request a document receipt when sending the electronic mail. PLEASE NOTE: Electronic mail comments will NOT be considered part of the official written comment period unless they are sent to the email address indicated in this notice.

(4) Hand delivered to the receptionist on duty at the thirteenth floor reception desk, Office of Legal Counsel, Indiana Government Center North, 100 North Senate Avenue, Indianapolis, Indiana.

Regardless of the delivery method used, in order to properly identify each comment with the rulemaking action it is intended to address, each comment document must clearly specify the LSA document number of the rulemaking.

All comments must be postmarked, faxed, or time stamped not later than October 10, 2014. Hand-delivered comments must be delivered to the appropriate office by 4:45 p.m. on the above-listed deadline date.

Additional information regarding this action may be obtained from Susan Bem, Rules Development Branch, Office of Legal Counsel, (317) 233-5697 or (800) 451-6027 (in Indiana).

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

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.

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

Affected: IC 13-12; IC 13-14-4-3; IC 13-16-1

Sec. 2. The following 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:

			Emission Limitations
	Source	Facility Emission Unit Description	lbs./MMBtu	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) (1) Indianapolis Belmont	Incinerator 1	2.0 pounds per ton	14.19
	Sludge Incinerator	Incinerator 2	2.0 pounds per ton	14.19
	Source ID No. 00032	Incinerator 3	2.0 pounds per ton	14.19
		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	2722 W	1.25	114.75
	Agriculture and Nutrition	2726 S	1.25	49.1
	Specialties	186 N	1.25	46.0
	Source ID No. 00315	2707 V	1.25	20.0
		112 E	0.0**	0.0**
		2710 P	0.0**	0.0**
		Riley	1.25	64.75
		B & W	1.25	49.1
		2724 W	1.25	26.3
		2714 V	1.25	18.8
		2729 Q	1.25	3.8
		2740 Q	1.25	7.5
		732714	1.25	45.0
		2728 S	1.25	7.5
		Still	0.0**	0.0**
		Kettle	0.0**	0.0**
		2607 T	0.0**	0.0**
		702611	0.0**	0.0**
		722804	0.0**	0.0**
		2706 Q	0.0**	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

*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.

SECTION 3. 326 IAC 7-4-2.1 IS ADDED TO READ AS FOLLOWS:

Affected: IC 13-15; IC 13-17

Sec. 2.1. The following 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)	Emission Limit (lbs/MMBtu)
(1)	Citizens	(A) Boiler 17	72.6	0.3
	Thermal - Perry K	(B) Boiler 18	72.6	0.3
	Source ID No. 00034	(C) Boilers 11, 12, 13, 14, 15, and 16	Burn natural gas
(2)	Belmont Wastewater Treatment Plant Source ID No. 00032	(A) Main Stack I1-I4	Comply with SO2 limit in 40 CFR 60, Subpart MMMM* or 40 CFR 60, Subpart LLLL*
		(B) Incinerator I5	Not operating
		(C) Incinerator I6	Not operating
		(D) Incinerator I7	Not operating
		(E) Incinerator I8	Not operating
(3)	Rolls Royce	(A) Boiler 0070-58	Burn natural gas
	Source ID No.	(B) Boiler 0070-59	Burn natural gas
	00311	(C) Boiler 0070-62	Burn natural gas
		(D) Boiler 0070-63	Burn natural gas
		(E) Boilers 0070-64	Burn landfill gas
		(F) Boiler 0070-65	Burn natural gas
		(G) Generating Turbine 0070-80	Burn natural gas or landfill gas
		(H) 501k Turbine Generator	Burn landfill gas
		(I) 2 Gas Turbine Engines 0070-66		0.1
		(J) 12 Gas Turbine Engines 0070-67	1,000 hour calendar year operating limit	0.1
		(K) 3 Gas Turbine Engines 0070-68c, 0070-68d, and 0070-68e		0.1
		(L) 2 Gas Turbine Engines 0070-68a and 0070-68b	Burn natural gas
		(M) 3 Gas Turbine Engines 0070-69		0.1
		(N) Three Shack Heaters 0070-70	Burn natural gas
		(O) Rental Generator	500 hour calendar year operating limit
		(P) Engine Test Cells (Plant 5 and 8)		0.1
		(Q) Engine Test Cell Plant 5 0070-N6	1,000 hour calendar year operating limit
(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	Burn natural gas
		(G) DAB Furnace 732714	Burn natural gas
		(H) Born Heater 722804	Burn natural gas
		(I) Born Heater Furnace BXS2706Q	Burn natural gas
		(J) EP Furnace EP2729Q	Burn natural gas
		(K) CB20 CB600-300 Boiler	Burn landfill gas
		(L) 50K CN5-400 Boiler	Burn landfill gas
		(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	(A) Main Stack S-100	73.2
	Source ID No. 00079	(B) WESP Stack	51.4
(6)	Indianapolis	(A) Boiler 9	Not operating
	Power & Light –	(B) Boiler 10	Not operating
	Harding St.	(C) Boiler 50	Burn natural gas
	Source ID No.	(D) Boiler 60	Burn natural gas
	00033	(E) Boiler 70	655.56	0.159
		(F) Gas Turbine 1	14.95	0.05
		(G) Gas Turbine 2	14.95	0.05
		(H) Gas Turbine 3	Not operating
		(I) Gas Turbine 4	43.75	0.05
		(J) Gas Turbine 5	43.35	0.05
		(K) Gas Turbine 6	Burn natural gas
		(L) Emergency Generator	500 hour calendar year operating limit
		(M) The following applies to the emission limits in clause (E):
		(i) The emission limit is an arithmetic average of all the valid data for emission rates recorded from a continuous emission monitoring system on a one (1) hour basis.
		(ii) Compliance shall be demonstrated with a continuous emission monitoring system that is installed, operated, and certified in accordance with 326 IAC 3-5.

*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.

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

Affected: IC 13-12; IC 13-14-4-3; IC 13-16-1

Sec. 3. The following 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:

	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	#1 Kewanee Boiler	0.36
	Source ID No. 00032	#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	Murray Iron Works Boiler A	0.51
	Industries Source ID No. 00045	Murray Iron Works Boiler B	0.51
		Clayton Boiler (Standby)	0.51
		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 (3) Duke Indiana 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	#1 Boiler	0.45
	Source ID No. 00046	(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

SECTION 5. 326 IAC 7-4-3.1 IS ADDED TO READ AS FOLLOWS:

Affected: IC 13-15; IC 13-17

Sec. 3.1. The following 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)	Emission Limit (lbs/MMBtu)
(1)	Wabash River Combined	Combustion Turbine Unit 1A	333.76	0.195
	Cycle Source
	ID No. 00147
(2)	SG Solutions Source ID	(A) Tail Gas Incinerator Stack EP1	527.0
	No. 00091	(B) Process Flare Unit 2	77.0
(3)	SONY Digital	(A) #1 Kewanee Boiler		0.05
	Audio Disc Source	(B) #2 Kewanee Boiler		0.05
	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) Murray Iron Works Boiler A		0.05
	Source ID No. 00045	(B) Murray Iron Works Boiler B		0.05
		(C) Clayton Boiler (Standby)	Burn natural gas
		(D) Nebraska Boiler		0.51
(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	(A) 2 Keeler Boilers		0.36
(7)	Duke Energy -	(A) Boiler 6	1,499.5	0.5
	Wabash Source ID No. 00021	(B) Diesel Generators 7A, 7B, and 7C	500 hour calendar year operating limit (each)	0.05
		(C) The following applies to clause (A):
		(i) The emission limit is an arithmetic average of all the valid data for emission rates recorded from a continuous emission monitoring system on a one (1) hour basis.
		(ii) Compliance shall be demonstrated with a continuous emission monitoring system that is installed, operated, and certified in accordance with 326 IAC 3-5.

SECTION 6. 326 IAC 7-4-11 IS AMENDED TO READ AS FOLLOWS:

Affected: IC 13-1-1; IC 13-7

Sec. 11. Indianapolis Power and Light (IPL) Pritchard Generating Eagle Valley 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
	Units 4, 5, and 6 after September 30, 1990	3.04 each

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

Affected: IC 13-15; IC 13-17

Sec. 11.1. Indianapolis Power and Light (IPL) – Eagle Valley, Source ID No. 00004, located in Morgan County, shall burn natural gas in the following units:

SECTION 8. 326 IAC 7-4-15 IS ADDED TO READ AS FOLLOWS:

Affected: IC 13-15; IC 13-17

Sec. 15. (a) The following 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)	Emission Limit (lbs/MMBtu)
(1)	IPL Petersburg	(A) Unit 1	330.0	0.15
	Source ID No.	(B) Unit 2	621.6	0.15
	00002	(C) Unit 3	2,049.8	0.37
		(D) Unit 4	1,942.5	0.35
		(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) The emission limits in subsection (a) are an arithmetic average of all the valid data for emission rates recorded from a continuous monitoring system on a one (1) hour basis, except as allowed under subsection (d).

(c) Compliance shall be demonstrated with a continuous emission monitoring system that is installed, operated, and certified in accordance with 326 IAC 3-5.

(d) As an alternative to the emission limits in subsection (a)(1)(A) though (a)(1)(D), IPL Petersburg 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

SECTION 9. THE FOLLOWING ARE REPEALED: 326 IAC 7-4-2; 326 IAC 7-4-3; 326 IAC 7-4-11.

SECTION 10. SECTION 9 of this document takes effect January 1, 2017.

Notice of Public Hearing

DIN: 20140910-IR-326110356SNA

Composed: Apr 25,2024 10:52:09AM EDT

A PDF version of this document.